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Home My WebLink About201-094 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Q, 0 I - ©9 1 'J' fin Mr. Tom Maunder I V ` 5• Alaska Oil and Gas Conservation Commission • 333 West 7 Avenue Vs Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPC -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPC -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, • Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPC -Pad 10/9/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPC-01 1811430 50029206630000 Sealed conductor NA NA NA NA NA MPC-02 1821940 50029208660000 Sealed conductor NA NA NA NA NA MPC-03 1820500 50029207860000 Sealed conductor NA NA NA NA NA MPC-04 1821260 50029208010000 Sealed conductor NA NA NA NA NA MPC -05A 1842430 50029212440100 Tanko conductor NA NA NA NA NA MPC-06 1842410 50029212570000 Tanko conductor NA NA NA NA NA MPC-07 1850020 50029212660000 Tanko conductor NA NA NA NA NA MPC-08 1850140 50029212770000 Tanko w/o top NA NA NA 3.4 10/9/2011 MPC-09 1850360 50029212990000 Tanko conductor NA NA NA NA NA MPC-10 1850150 50029212780000 Tanko conductor NA NA NA NA NA MPC-11 1850590 50029213210000 Tanko conductor NA NA NA NA NA MPC -12A 1990910 50029213730100 Tanko conductor NA NA NA NA NA MPC-13 1850670 50029213280000 Tanko conductor NA NA NA NA NA MPC -14 1850880 50029213440000 1.8 NA 1.8 NA 5.1 8/31/2011 MPC-15 1851030 50029213580000 Sealed conductor NA NA NA NA NA MPC-16 1851100 50029213640000 Sealed conductor NA NA NA NA NA MPC-17 1852630 50029214730000 Tanko conductor NA NA NA NA NA MPC-18 1852690 50029214790000 Abandoned NA NA NA NA NA MPC-19 1852960 50029215040000 Tanko conductor NA NA NA NA NA MPC-20 1890150 50029219140000 Tanko conductor NA NA NA NA NA MPC -21 1940800 50029224860000 4.6 NA 4.6 NA 8.5 8/29/2011 MPC -22A 1951980 50029224890100 38 NA Need top job MPC -23 1960160 50029226430000 1.9 NA 1.9 NA 17.0 8/28/2011 ----,i MPC-24 2010940 50029230200000 1.6 NA 1.6 NA 20.4 8/28/2011 MPC -25A 1960210 50029226380100 1.7 NA 1.7 NA 17.0 8/28/2011 MPC-26 1952060 50029226340000 1.8 NA 1.8 NA 17.0 8/28/2011 MPC -28A 2051630 50029226480100 1.6 NA 1.6 NA 10.2 8/29/2011 MPC-36 1980010 50029228530000 4.5 NA 4.5 NA 45.9 8/29/2011 MPC-39 1972480 50029228490000 5.5 NA 5.5 NA 49.3 8/29/2011 MPC-40 2002130 50029228710000 0.75 NA 0.75 NA 5.1 8/29/2011 MPC-41 2010780 50029230140000 0.5 NA 0.5 NA 8.5 8/31/2011 MPC -42 2040280 50029231960000 1.5 NA 1.5 NA 13.6 8/30/2011 MPC-43 _ 2040390 50029232000000 3.3 NA 3.3 NA 30.6 8/30/2011 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS~ON ~~C~IVED i~ttl 7 0 2.014 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ^ Oil ^ Gas ^ SPLUG ^ Other ®Abandoned ^ Suspended 20AAC 25.105 zoAAC zs.»o ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other No. of Completions Zero 1 b. ~ ®Developmer~n~ oratory ^ Service Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., 6t.AtLB 12/28/2009 12. Permit to Drill Number: 207-094 309-371 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded: 07/13/2001 13. API Number: 50-029-23020-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached: 07/25/2001 14. Well Name and Number: MPC-24 1171 FSL, 2446 FEL, SEC. 10, T13N, R10E, UM Top of Productive Horizon: 1208' FNL, 34' FEL, SEC. 15, T13N, R10E, UM g, KB (tt above MSL): 44.80 GL (tt above MSL): 16.2' 15. Field /Pool(s): Milne Point Unit / Kuparuk River Total Depth: 1382' FNL, 5' FWL, SEC. 14, T13N, R10E, UM 9. Plug Back Depth (MD+TVD): 8045' 6898' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 558013 y_ 6029452 Zone- ASP4 10. Total Depth (MD+TVD): 8406' 7228' 16. Property Designation: ADL 047434, 025516 &047437 TPI: x- 560448 y- 6027092 Zone- ASP4 Total Depth: x- 560489 Y- 6026919 Zone- ASP4 11 • SSSV Depth (MD+TVD): N/A 17. Land Use Permit: 18. Directional Survey: ^ Yes ®No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore: N/A ft MSL 20. Thickness of Permafrost (lVD): 1800' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIR, GR, GYRO, ABGR, RES, PWD, NEU, DENS, CCL 22. Re-DrilULateral Top Window MDffVD: N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FL GRADE TOP BOTTOM TOP BOTTOM. SIZE CEMENTING RECORD PULLED 20" 92# H-40 31' 113' 31' 113' 30" 26 sx Arcticse A rox. - 8" 0# -0 3 ' 4 12-1I4" 714 x rm fros ' x as ' 7" 26# L-80 2 ' 7679' 28' 658 ' 8-1/2" 17 sx Class 'G' 4-1/2" 12. L-80 7494' 840 ' 6424' 7228' 6-1/8" 11 sx Class 'G' 24. Open to production or injection? ^ Yes ®No 25. TueING RECORD If Yes, IISt each Interval Open (MD+TVD of To Perforation Size and Number): & Bottom SIZE DEPTH SET MD PACKER SET MD / TVD p ; Workstrin 4-1/2", 12.6#, L-80 7495' 7383' / 6332' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~.~ {~g~~ j. ~~~~ ~, ~~~~ DEPTH INTERVAL (MD AMOUNT AND KIND OF MATERIAL USED ~ ~ t "G 8040' Set Whipstock 8040' P&A Perfs w/ 16.7 Bbls Cement 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: Hours Tested: Production For Test Period OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 28. CORE DATA Conventi onal Core(s) Acqu ired? ^ Yes ® No Sidewall Core(s) Acquired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None Form 10-407 Revised 12/2009~p~ ~ 2 ~ 9n~ONTINUED ON REVERSE Submit Original Only 29. GEOLOGIC MARKERS (List all formati ons and ma encountered): 30. NATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Kuparuk 7834' 6713' None Kuparuk D 7834' 6713' Kuparuk C 7978' 6839' Kuparuk B 7991' 6850' Kuparuk A 8140' 6983' Kuparuk A3 8143' 6986' Kuparuk A2 8184' 7023' Miluveach 8262' 7094' Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoin is true and correct to the best of my knowledge. Signed: Terrie Hubble Title: Drilling Technologist Date: 2~~~ MPC-24 201-094 309-371 Prepared By NameMumber. Ter-ie Hubble, 564-4628 Well Number Permit No. /Approval No. Drilling Engineer: Sean McLaughlin, 564-4387 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelty Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only ~ i MPC-24, Well History (Pre Rig Sidetrack) Date Summary 11/11/09 T/I/0=100/250/740 Pre RWO freeze protect. Pump 15 bbls diesel down Tbg. Pump 2 bbls 60/40 meth, 3 bbls diesel and 2 bbls 60/40 meth down Prod. Lat. Bleed Prod. Lat. to zero. Pump 2 bbls 60/40 meth, 3 bbls diesel and 2 bbls 60/40 meth down Test Lat. Bleed Test Lat. to Zero. FWHP = 50/250/340. Swab, Wing, SSV closed. Master, I, O open. NOVP. 11/13/09 Freeze protect Prod. and Test Latural. Pump 4 bbls down Prod. Lat. Bleed Lat. to zero. Pump 4 bbls down Test Lat. Bleed Lat. to zero. Notify Operator that Prod. and Test Lat. pressures are shut at header and bleed to zero. Swab, Wing, SSV closed. Master, I, O open. NOVP. 11/16/09 WELL S/I ON ARRIVAL. PULLED 1" DGLV FROM 6852' MD (POCKET OPEN). PULLED 1" DPSOV & SET 1" DGLV C~ 142' MD. RIH W/ 1.74" CENT.,S.S, DUAL SPARTEK GAUGES. TAGGED ESP C~ 7023' SLM. MAKE 3 HOUR STOP C~3 7022' SLM. 11/17/09 MADE 3 HOUR STOP ~ 7022' SLM / 7042' MD. MADE 20 MINUTE STOP C~ 6522' SLM / 6542' MD. WELL LEFT S/I. 11/17/09 The Well Support Techs rigged up and set a BPV and removed the wellhouse, flowlines and foundation. They then installed a 2nd IA valve for the RWO. NOTE: The BPV was left IN. ,Nabors 4ES moved on this well to pull the ESP and run workstring (11/21/09 - 11/27/09 `'r..__ . _... _.. 11/30/09 ASSIST WELL SUPPORT W/ BPV REMOVAL. PULL BALL & ROD FROM RHC BODY C~3 7462' MD. PULLED 1"SHEAR VALVE FROM ST #1 C~ 3039' MD. MADE SEVERAL ATTEMPTS TO SET 1" BK- DGLV IN ST #1. RAN SWIVEL, 3.68" CENT, 3' x 1-7/8" stem, 4-1/2" OK-6 TO SET 1" BK-DGLV IN ST #1 C~3 3,039' MD. RAN 4-1/2" GR (steel), PULL 4-1/2" RHC FROM 7,462' MD. RAN 3., 4-1/2" BLB BRUSH OUT OF TAIL PIPE TO PUSH DEBRIS OUT OF TUBING. RAN 4-1/2" GR (steel), W/DMY WHIPSTOCK TO 7,983' SLM (8,100' MD). (3.66"=od, 20.5' long) WELL LEFT S/I, TURN OVER TO DSO. JOB COMPLETE. 12/03/09 WELL SHUT IN UPON ARRIVAL. INITIAL T/I/O: 12/0/0 ARRIVE ON LOCATION AND RU TO SET 3.63" BAKER WHIPSTOCK. 12/04/09 WELL SHUT IN UPON ARRIVAL. INITIAL T/I/O: 12/0/0 SET BAKER 3.63" WHIPSTOCK IN 4.5" LINER. TOP OF WHIPSTOCK SET AT 8040'., WHIPSTOCK SET WITH ORIENTATION OF 283 DEG (77 DEG LOHS). TWO RA TAGS LOCATED AT 8049', 9' BELOW TOP OF WHIPSTOCK. DID NOT TAG TD. WELL LEFT SHUT IN. SWAB /WING /SSV-C, MASTER-O. FINAL T/I/O: 0/0/0 JOB COMPLETE. 12/11/09 MIRU CT unit. RIH with 2.5" BJN cementing BHA. Tag whipstock and correct depth to eline set whipstock depth of 8040'. Park nozzle at 7980' and pumped 16.7 bbls of 15.8 pp_ sa.~ment. Achieve 500 psi bump and lay in remaining cement 1:1. Reach squeeze pressure of 2100 psi and begin hesitation squeeze. Hold for 30 minutes lost 80 psi. Clean cement to top of whipstock wash across iewelry while _ POOH. Freeze protect well with 38 bbls diesel. 12/12/09 Perform weekly BOP test chain inspection RDMO. Notify DSO of well status. Job Complete. -.- 12/24/09 The Well Support Techs rigged up and set a back pressure valve and then rotated the tree for the Nordic Rig. NOTE: The BPV was left IN. / Z~Z- G /p ( /~l l l~ ~, I U~ r ~ i ~- Z-- ~ ~T ~~ ~ ~r e j~ Page 1 of 1 BP EXPLORATION Page 1 of 6 Operations Summary Report Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: WORKOVER Start: 11/20/2009 End: 11/27/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/27/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To '~, Hours Task Code NPT j Phase Description of Operations 11/21/2009 00:00 - 06:00 6.00 RIGD P PRE RIG DOWN OPERATION -SCOPE DOWN AND LAY OVER DERRICK. -AOGCC GIVEN 24-HR. NOTICE OF IMPENDING BOPE TEST. -NOTICE GIVEN AT 11:50-HRS. ON 11/20/2009. -CHUCH SCHEVES W/AOGCC WAIVED TEST WITNESS 06:00 - 07:00 1.00 MOB P PRE MOVE PITS, PIPE SHED AND SUB OFF WELL. -PICK UP RIG MATS AND HERCULITE AROUND WELLHEAD. 07:00 - 09:00 2.00 MOB P PRE MOVE RIG COMPONENTS FROM MPE-14 TO MPC-24 09:00 - 12:30 3.50 RIGU P PRE SPOT SUB, PITS AND PIPESHED. -RAISE AND SCOPE DERRICK. -HOOK UP LINES BETWEEN SUB AND PITS. 12:00 - 15:00 3.00 RIGD P PRE RAISE AND SCOPE DERRICK. 15:00 - 18:00 3.00 RIGU P PRE ACCEPTED RIG AT 17:00 HRS. -RU, SPOT TIGER TANK AND HOOK UP LINES. -RU CIRCULATING LINES TO TREE WING VALVE AND IA. -TEST LINES TO 3,500 PSI. -PASS. 18:00 - 19:00 1.00 RIGU P PRE PU AND RU LUBRICATOR -TEST WITH DIESEL TO 500 PSI. -PASS. -PULL BPV, -T/I/O = 334 / 225 / 50. 19:00 - 23:30 4.50 KILL P DECOMP CIRCULATE KILLFLUID, 8.45 PPG 120 DEG SEAWATER. -BLEED DOWN TBG AND IA. -PUMP 58 BBLS HEATED SEAWATER DOWN THE TBG 3 BPM ~ 0/30 PSI -NO RETURNS -COMFIRM W/ADW RWO ENGINEERING ON PLAN FORWARD. -BULL HEAD 300 BBLS HEATED SEAWATER DOWN THE IA 3 BPM ~ 30-1080 PSI -PUMP 50 BBLS DOWN THE TBG, 3 BPM ~ 30-980 PSI 23:30 - 00:00 0.50 KILL P DECOMP -MONITOR WELL -WELL WAS DEAD. WELL ON VAC BOTH TBG AND IA ', -PUMPED A TOTAL OF 408 BBLS. -LOST 161 BBLS TO THE FORMATION. 11/22/2009 00:00 - 01:30 1.50 WHSUR P DECOMP (FMC) SET TWC WITH T-BAR -TESTED FROM ABOVE TO 3500 PSI FOR 10 CHARTED MIN -CONDUCTED ROLLING TEST FROM BELOW INJECTED 50 BBLS, REACHED 500 PSI. 01:30 - 03:30 2.00 WHSUR P DECOMP ND PRODUCTION TREE AND ADAPTER FLANGE. -TREE WILL STAY ON LOCATION 03:30 -.06:00 2.50 BOPSU P DECOMP NU BOPE. -RIG UP BOPE TEST EQUIPMENT. 06:00 - 07:00 1.00 BOPSU P DECOMP INSPECT DERRICK SERVICE DRAWORKS 07:00 - 13:30 6.50 BOPSU P DECOMP TEST BOPE PER BP/AOGCC REQUIREMENTS: BOP CONFIGURATION: -13-5/8" HYDRIL GK 5000. -BLIND SHEAR RAMS. -SPACER SPOOL. Nnntea: vzuizuiu i:oini ann BP EXPLORATION Page 2 of 6 Operations Summary Report Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: WORKOVER Start: 11/20/2009 End: 11/27/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/27/2009 Rig Name: NABOBS 4ES Rig Number: 4ES ' ~ ~ Operations Code NPT Phase Description of From - To Hours Task Date 11/22/2009 07:00 - 13:30 6.50 BOPSU P DECOMP -2 7/8" X 5" VARIABLE BORE RAMS. -TEST CHOKE MANIFOLD, BLINDS, 2 7/8" X 5" VBR'S, -MANUAL CHOKE, HCR CHOKE, MANUAL KILL, HCR KILL, -FLOOR VALVES. - E T TO 250 PSI LOW AND 3 500 PSI HIGH PRESSURE. -TESTED 2-7/8" X 5" VBR'S WITH 2-7/8" AND 4 1/2" TEST JOINTS. -TESTED ANNULAR WITH 2-7/8" TEST JOINT. -EACH TEST WAS HELD FOR 5 CHARTED MINUTES. -TEST WITNESSED BY WSL & TP. -TESTED KELLY 200 PSI BUILD UP FROM 1600 PSI = 52 SECONDS. -FULL BUILD UP TO 3000 PSI = 208 SECONDS. -4 BOTTLES x 1525 PSI. -CHUCK SCHEVES WAIVED AOGCC RIGHT TO WITNESS BOPE TESTING AT 11:00-HRS. ON 11/20/2009. 13:30 - 14:30 . 1.00 BOPSU P DECOMP R/U DUTCH SYSTEM 14:30 - 16:00 1.50 BOPSU DECOMP WAIT ON WELL SUPPORT LUBRICATOR FROM MPC-14 -R/U ESP CABLE SHEAVE DRAIN HOSE AND ELEPHANT TRUNK -CHANGE OUT GERANIMO CARD. 16:00 - 17:00 1.00 BOPSU P DECOMP 2010 BP TEAM ALASKA SAFETY HANDBOOK TRAINING -CONDUCTED BY NABOBS SAFETY REP PAUL HOLLEY. 17:00 - 19:00 2.00 WHSUR P DECOMP PULL TWC -M/U AND TEST LUBRICATOR TO 500 PSI -PULL TWC -UD LUBRICATOR -R/D DUTCH SYSTEM. 19:00 - 20:00 1.00 PULL P DECOMP WEEKLY SAFETY MEETING -NABOBS SAFETY PAUL HOLLEY DID TASH BOOK TRAINING W/CREWS. 20:00 - 21:00 1.00 WHSUR P DECOMP PULL TBG HANGER. -FMC BACKED OUT LOCK DOWN SCREWS. -PULLED 2-7/8" TUBING HANGER. -PULL OFF SEAT AT 50-K WITH 55-K PUW. -BREAK OUT LAY DOWN HANGER. 21:00 - 21:30 0.50 PULL P DECOMP CIRCULATED A TUBING VOL. 40 BBLS WITH 8.5 SEAWATER. -REQUIRED 22 BBLS TO FILL. THE HOLE. -3 BPM AT 0-120 PSI. 21:30 - 00:00 2.50 PULL P DECOMP POH W/ 2-7/8" ESP COMPLETION ASSEMBLY & CABLE. -LAYING DOWN TO PIPE SHED 2-7/8' TBG. 11/23/2009 00:00 - 06:00 6.00 PULL P DECOMP CONT: POH W/ 2-7/8" ESP COMPLETION ASSEMBLY & CABLE. -LAYING DOWN TO PIPE SHED 2-7/8' TBG. 06:00 - 06:30 0.50 PULL P DECOMP RIG SERVICE AND PRE-TOUR CHECKS. 06:30 - 07:30 1.00 PULL P DECOMP CONT. UD 2 7/8 TBG. 07:30 - 10:30 3.00 PULL P DECOMP ESP rnmea: irzurzu~u rain Nm ~~ $P EXPLORATION Page 3 of 6 Operations_Summary Report Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: WORKOVER Start: 11/20/2009 End: 11/27/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/27/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To ~ Hours ~ Task Code ~ NPT ~ Phase Description of Operations 11/23/2009 07:30 - 10:30 --- 3.00 PULL P ---- DECOMP -UD PUMP AND MOTOR -LOWER ESP CABLE OVER SHEAVE IN DERRICK. 10:30 - 11:30 1.00 PULL P DECOMP LOAD PIPE SHED W/ 3.5" DP. -STRAP AND RABBIT -P/U BHA TO FLOOR 11:30 - 12:00 0.50 PULL P DECOMP INSTALL 6.9375" I.D. WEAR RING. 12:00 - 14:00 2.00 PULL P DECOMP BHA #1 -6.125" PACKER MILL W 2.5" OD EXT. -(4) BOOT BASKETS -XO, BUMPER JARS, OIL JARS, -(9) 4.75" DC's, PUMP-OUT-SUB. -TOTAL = 320.08 14:00 - 21:00 7.00 PULL P DECOMP RIH W/ 3.5", 15.5# DRILL PIPE -SINGLES FROM PIPE SHED -FEED WELL AT 20 BPH 21:00 - 00:00 3.00 PULL P DECOMP MILL PACKER PER BAKER REP. -RIH TO TOP OF FISH AND ESTABLISH MILLING PARAMETERS, -TAGGED UPON 4.5" TUBING ~ 7,394' WITH 227 JNTS + 11' -PUW 110-SOW 82-PU K-PUW 115-SOW 87-EST. -PARAMETERS-60-80 RPM, 195 AMPS ROTATING TORQUE -WT 10-15 K -2/4 BPM C~ 150/770 PSI-ROT. -MILL F/. 7394' TO 7,402' -EST LOSS RATE DURING MILLING OPS. 50 BPH 11/24/2009 00:00 - 03:00 3.00 CLEAN P DECOMP CONT: MILL PACKER PER BAKER REP. -MILLING AT 7402' -PUW 115-SOW 87 -PARAMETERS-195 AMPS ROTATING TORQUE -WT 10-15 K -2/4 BPM ~ 150/770 PSI-ROT -MILLED THROUGH SLIPS ,PACKER CAME LOOSE AND FELL TO TOP OF 4.5" LINER. -EST. LOSS RATE DURING MILLING OPERATION @ 50 BPH 03:00 - 04:00 1.00 CLEAN P DECOMP CHASED PACKER DOWN TO TOP OF 4.5 "PRODUCTION LINER -W/ 229 JNTS +34' C~ 7,477' -PARAMETERS 80 SPM, 180 AMPS ROT, 15 K WT , 40 SPM 04:00 - 06:00 2.00 CLEAN P DECOMP PUMP 20 BBL HIGH VIS SWEEP ALL THE WAY AROUND -PUMP 3-4.5 BPM ~ 410-1060 PSI. -LOSS RATE OF 50-60 BPH 06:00 - 06:30 0.50 CLEAN P DECOMP RIG SERVICE AND PERFORM PRE-TOUR CHECKS. 06:30 - 10:30 4.00 CLEAN P DECOMP POH F/ 7,477' MD -SERVICE BOOT BASKETS -RECOVERED (4) GALLONS METAL CUTTINGS. 10:30 - 11:00 0.50 CLEAN P DECOMP CLEAN AND CLEAR RIG FLOOR. 11:00 - 12:00 1.00 CLEAN P DECOMP MU BHA #2 -ITCO SPEAR, BUMPER SUB, OIL JAR, (9) 4 3/4" DC"s, PUMP-OUT-SUB = 301.25 12:00 - 15:00 3.00 CLEAN P DECOMP RIH WITH BHA # 2 -T/ 7,422' MD Printed: 1/20/2010 7:51:11 AM BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: WORKOVER Start: 11/20/2009 End: 11/27/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/27/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date `From - To Hours Task Code NPT Phase Description of'Operations 11/24/2009 15:00 - 16:00 1.00 CLEAN I P 16:00 - 20:00 I 4.001 CLEAN I P 20:00 - 22:00 I 2.001 CLEAN I P 22:00 - 23:00 I 1.001 CLEAN I P 23:00 - 00:00 1.00 CLEAN P 11/25/2009 100:00 - 01:30 I 1.501 CLEAN I P 01:30 - 04:00 I 2.501 CLEAN I P 04:00 - 06:00 2.00 CLEAN I P 06:00 - 06:30 0.50 CLEAN P 06:30 - 08:00 1.50 CLEAN P 08:00 - 11:00 3.00 CLEAN P 11:00 - 13:00 2.00 CLEAN P 13:00 - 13:30 0.50 CLEAN P 13:30 - 15:30 2.00 WHSUR P DECOMP SPEAR FISH -P/U KELLY -230 JOINTS + 20' TO 7,477' MD -3 BPM / 430 PSI. PUW = 112 (K). SOW = 90 (K) -ENGAGE SPEAR AT 7,477' MD -OBSERVED 15 (K) OVER PULL -SET BACK KELLY DECOMP POH F/ 7,477' -UD (2) JOINTS DP -POH W/ 76 JNTS -FEED W ELL AT -20 BPH +DBL-DISPLACMENT. DECOMP LD BHA # 2 7" BAKER ZXP PACKER AND 4.5"TAIL PIPE /~ DECOMP MU CLEAN OUT BHA #3 -3-3/4" MILL,PAC COLLAR,TBR POLISH MILL,(4)-JUNK BASKETS,7" CSG SCRAPER, BUMPER SUB,OIL JAR, (9) 4 3/4" DC"s, PUMP-OUT-SUB = 368.48 DECOMP RIH W/ 76 JNTS OF 3.5", 15.5# DRILL PIPE -WITH CLEAN OUT BHA# 3. -FEED W ELL AT 20 BPH DECOMP CONT: RIH W/ CLEAN OUT BHA# 3 ON 3.5", 15.5# DRILL PIPE -FEED W ELL AT 20 BPH -76 STANDS DECOMP RECIPROCATE 7" SCRAPER ACROSS PACKER SETTING. F/ 7,300' T/ 7,423' -ESTABLISH CIRCULATION ~ 7423' W/ 3-4 BPM ~ 680-1600 PSI -50 BPH LOSS RATE -POLISH TOP OF LINER AT 7,494' -PARAMETERS -PUW- 120 SOW-97, 3000-3800 FT/LB TORQUE DECOMP CIRCULATE THE LONG WAY WITH 2066E HIGH VIS SWEEP. -3-4 BPM ~ 680-1000 PSI -50-70 BBL LOSS RATE WHILE PUMPING -SAW SMALL AMOUNT OF METAL CUTTINGS AT SHAKER -WITH SOME GAS BUBLES DECOMP RIG SERVICE AND PERFORM PRE-TOUR CHECKS. DECOMP CUT AND SLIP 84' DRILL LINE. DECOMP POH WITH BHA # 3 -F/ -7,400' MD -FEED WELL WITH SEAWATER -~ 20 BPH +DBL DISPLACMENT. DECOMP UD BHA # 3 -SERVICE BOOT BASKETS -RECOVERED 3 CUPS OF FINE METAL CUTTINGS.. -NO-GO COMFIRMS DEPTH @ -7,490' MD. -REMOVE BHA FROM FLOOR. DECOMP CLEAN RIG FLOOR. DECOMP CHANGE PACK-OFF Printed: 1/20/2010 7:51:11 AM • • BP EXPLORATION Page 5 of 6 Operations Sumrnary,Report !,Legal Well Name: MPC-24 'Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: WORKOVER Start: 11/20/2009 End: 11/27/2009 Contractor Name: NABOBS ALASKA DRI LLING I Rig Release: 11/27/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date.... .From'- To Haurs ~ Task Code NPT Phase Description of Operations 11/25/2009 13:30 - 15:30 2.00 WHSUR P DECOMP -PULL WEAR RING -BOLDS AND PULL 7" PACK-OFF WITH 8(K) -FLUSH AND INSTALL NEW FMC MANDREL PACK-OFF -FMC TO RILDS AND TEST HANGER FLANGE AND PACK-OFF SEALS TO 5,000 PSI F/ 30 MINUTES. -INSTALL WEAR RING. 15:30 - 16:30 1.00 CLEAN P DECOMP MU BHA # 4 -PU 7" RTTS PACKER, CIRCULATE SUB -RIH TO _7,450' SET RTTS -PRESSURE TEST CSG TO 2000 PSI FOR 30 IN (GOOD TEST) 16:30 - 20:00 3.501 CLEAN P 20:00 - 21:00 I 1.001 CLEAN I P 21:00 - 22:30 1.501 CLEAN P 22:30 - 00:00 1.50 CLEAN P 11/26/2009 00:00 - 03:30 3.50 CLEAN P 03:30 - 04:00 0.50 WHSUR P 04:00 - 06:00 2.00 CLEAN P 06:00 - 15:00 I 9.00 15:00 - 16:00 I 1.00 16:00 - 20:00 I 4.00 20:00 - 20:30 0.50 RUNCOI~VIP 20:30 - 21:30 1.00 WHSUR P 21:30 - 00:00 I 2.501 WHSUR I P DECOMP RIH W/ 7" RTTS PACKER DECOMP SET PACKER -TEST CASING TO 2,000 PSI FOR 30 CHARTED MIN. (GOOD TEST) DECOMP ONSET RTTS AND ALLOW ELEMENTS TO RELAX -CIRCULATE 64 BBLS, 4 BPM C~ 560 PSI DECOMP POH W/ 3.5" DP LAYING DOWN TO PIPE SHED DECOMP POH W/ 3.5" DP LAYING DOWN TO PIPE SHED -BREAK OUT AND LD COLLARS AND CIRCULATING. DECOMP -PULL WEAR BUSHING DECOMP CLEAN AND CLEAR RIG -RU TO RUN 4.5" WORK STRING TUBING EQUIPMENT AND TORQUE TURN EQUIPMENT - FINISH LOADING PIPE SHED WITH 4.5" TUBING AND JEWLERY. RUNCMP PU & RUN 4-1/2" TBG WORK STRING FOR CTD OPERATIONS. -WITH BAKER PREMIER PACKER AND GLM ASSEMBLY. -RUN 176 JNTS OF 4-1/2", 12.6#, L-80, IBT TUBING. -OPTIMUM TORQUE 3,400 FT/LBS. -USING BEST OF LIFE 2000 THREAD COMPOUND ON ALL IBT-M CONNECTIONS. RUNCMP SPACE-OUT -NO / GO AT 7,498' MD -LD (3) JOINTS. -PU PUP'S (9.84',9.84', 7.81', 5.11', 3.83',) -MU LANDING JOINT WITH TIW VALVE. RUNCMP STAND DOWN FOR THANKSGIVING. CREW SENT TO MILNE PIONT CAMP FOR DINNER. RUNCMP PTSM , PJSM FOR LANDING HANGER. TUBHGR LAND HANGER ,RILDS BY FMC - 75K UP WT - 64K DOWN WT TUBHGR DROP BALL TO SET AND TEST PACKER. -TEST LINES TO 4200 PSI -PRESSURE UP TO 4200 PSI AND SET PACKER. -TEST TBG TO 3500 PSI FOR 30 CHARTED MIN, TEST GOOD -BLEED DOWN TO 1500 PSI. -PRESSURE TEST TO 2000 ON THE IA FOR 15 MIN, TEST GOOD Printed: 1/20/2010 7:51:11 AM • BP EXPLORATION Page 6 of 6 Operations Summary Report Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: WORKOVER Start: 11/20/2009 End: 11/27/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/27/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours .Task Code `NPT Phase Description of Operations 11/26/2009 21:30 - 00:00 2.50 WHSUR P TUBHGR -BLEED OFF TBG AND SHEAR DCK VALVE, PUMP BOTH WAYS 10 BBLS TO ENSURE FULLY OPEN 11/27/2009 00:00 - 01:30 1.50 WHSUR P RUNCMP SET AND TEST TWC -FMC SET TWC -TESTED 3500 PSI FROM ABOVE- -TESTED 1000 PSI FROM BELOW BOTH FOR 10 CHARTED MIN. -ALL TESTS GOOD 01:30 - 03:30 2.00 BOPSU P RUNCMP PJSM FOR ND BOP OPERATIONS -ND BOPS ,REMOVE FLOW RISER AND BREAK OUT KILL AND CHOKE LINES. -SET BACK 03:30 - 07:00 3.50 WHSUR P RUNCMP NU ADAPTER FLANGE AND CAMERON 4-1/16" CTD TREE -TEST THE TUBING HANGER VOID AND TREE FOR 5 MIN. 07:00 - 08:00 1.00 WHSUR P RUNCMP RU TEST LUBRICATOR -PT TO 500 PSI AND PULL TWC 08:00 - 08:30 0.50 WHSUR P RUNCMP LITTLE RED SERVICES RU AND TEST LINES TO 2500 PSI -PUMP 70 BBLS OF DIESEL DOWN THE I.A. TAKING RETURNS OUT THE FLOWLINE -RD LRS ` 08:30 - 10:00 1.50 WHSUR P RUNCMP RU TO ALLOW WELL TO U-TUBE -OPENED THE IA TO THE CEMENT LINE TO THE MANIFOLD THROUGH THE KILL LINE TO THE TUBING 10:00 - 11:30 1.50 WHSUR P RUNCMP INSTALL BPV AND TEST -LITTLE RED SERVICES TO TEST FROM BELOW THROUGH THE SHEAR VALVE TO 1000 PSI FOR 5 MIN. 11:30 - 12:30 1.00 WHSUR P RUNCMP SECURE THE TREE AND CELLAR -BLOW DOWN AND R/D LINES. 12:30 - 13:00 0.50 WHSUR P RUNCMP AFTER ACTION REVIEW WITH CREW. -RIG RELEASE AT 13:00 HRS 11/27/2009. Printed: 1/20/2010 7:51:11 AM • BP EXPLORATION Page 1 oi~F3 Operations Summary Report Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 12/26/2009 09:00 - 12:00 3.00 MOB P PRE MOVE RIG FROM MPU E PAD TO MPU C PAD. 12:00 - 15:00 I 3.001 MOB I P I I PRE 15:00 - 18:15 3.25 RIGU P PRE 18:15 - 20:00 1.75 RIGU P PRE 20:00 - 22:15 2.25 RIGU P PRE 22:15 - 22:25 0.17 MOB P PRE 22:25 - 22:45 0.33 MOB P PRE 22:45 - 23:45 1.00 MOB P PRE 23:45 - 00:00 0.25 MOB P PRE 12/27/2009 00:00 - 03:00 3.00 RIGU P PRE 03:00 - 05:00 2.00 BOPSU P PRE 05:00 - 06:00 1.00 BOPSU P PRE 06:00 - 06:15 0.25 BOPSU P PRE 06:15 - 12:00 5.75 BOPSU P PRE 12:00 - 12:15 I 0.251 BOPSUp P I I PRE 12:15 - 16:00 3.75 BOPSU P PRE 16:30 - 18:00 1.50 RIGU PRE 18:00 - 18:20 0.33 RIGU P PRE 18:20 - 19:25 1.08 RIGU P PRE 19:25 - 20:00 0.58 RIGU P PRE 20:00 - 20:25 0.42 RIGU P PRE 20:25 - 22:15 1.83 RIGU P PRE 22:15 - 22:30 0.25 RIGU P PRE 22:30 - 23:00 0.50 BOPSU P PRE 23:00 - 23:50 0.83 RIGU P PRE 23:50 - 00:00 0.17 RIGU P PRE 12/28/2009 00:00 - 00:30 0.50 RIGU N SFAL PRE 00:30 - 01:00 0.50 RIGU P PRE 01:00 - 01:10 0.17 RIGU P PRE 01:10 - 01:55 0.75 RIGU P PRE 01:55 - 02:05 0.17 RIGU P PRE 02:05 - 02:20 0.25 RIGU P PRE PARK RIG AT ENTRANCE TO PAD WHILE PEFiMITING ISSUE IS RESOLVED. SPOT HERCULATE AND RIG MATS. SPOT RIG OVER WELLHEAD. LEVEL RIG. ACCEPT RIG AT 1300 HRS. CONTINUE TO RIG UP IN CELLAR. INSTALL BERM AND FLOOR BOARDS IN CELLAR, LOAD MPD LOOP INTO CELLAR ND TREE CAP, SET DOWN STACK AND CHECK POSITION PJSM FOR SKIDDING RIG SKID RIG TO REPOSITION OVER WELLHEAD LOAD 2-3/8" REEL INTO REELHOUSE MU HARDLINE IN REEL, BEGIN NU MPD LOOP SET DOWN BOP AND NIPPLE UP RIG UP MPD LOOP TO FLOW CROSS, SPOT IN TIGER TANK AND CUTTINGS BOX, HARDLINE CREW MU LINE TO TT AND PT. FILL BOP STACK CREW CHANGE. DISCUSS OPS. HSE ISSUES. MAKE RIG CHECKS AND ROUNDS. TEST BOP EQUIPMENT AS PER PERMIT TO DRILL, AOGCC BEGS, WELL PLAN, AND BP DWOP GUIDELINES. RECORD TEST ON TOTCO, CHART, AND SLB DIGITAL SYSTEMS. TEST MPD LOOP COMPONENTS, CHOKE MANIFOLD, AND CT HARDWARE. TEST WITNESS WAIVED BY J. JONES, AOGCC. CREW CHANGE. DISCUSS OPS. MAKE ROUNDS AND RIG CHECKS. CONTINUE TESTING BOP EQUIPMENT. PU INJECTOR AND STAB ONTO PACKOFFS PJSM FOR PULLING COIL ACROSS PULL COIL ACROSS FROM REELHOUSE TO INJECTOR AND STAB IN INJECTOR LOAD PITS WITH FLUID, CREW WALK ABOUNDS PJSM WITH NEW CREW FOR LOADING REEL W/ FLUID LOAD REEL WITH 5 BBLS MEOH, H2O SPACER, GEO-VIS. PJSM FOR PICKING UP INJECTOR AND STAGING ON WELL PU INJECTOR, MU TO LUBRICATOR SECTION, STAB ON WELL, PT INNER REEL VALVE PUMP SLACK BACK, POP OFF INJECTOR AND CUT 76' TO FIND ELINE. TEST ELINE, MEG TEST GOOD, TROUBLESHOOT BAD CONTINUITY TEST TROUBLESHOOT ELINE PROBLEMS, REPLACE TERMINAL BLOCK IN JUNCTION BOX, ELINE TEST IS GOOD INSTALL SLB CTC PULL TEST CTC TO 36K HEAD UP BHI UQC PT BHI UQC TO 4200 PSI PJSM FOR LOADING VALVE CREW TO FLOOR AND PULL Printed: 1/11/2010 12:38:54 PM • $P EXPLORATION Page 2 cr~'2~7" Operations Summary Report Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: REENTER+COMPLETE Start: 12/22/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task .Code `NPT Phase Description of Operations 12/28/2009 02:05 - 02:20 0.25 RIGU P PRE BPV 02:20 - 02:40 0.33 RIGU P PRE LOAD LUBRICATOR AND RODS TO FLOOR 02:40 - 03:30 0.83 RIGU P PRE LUBRICATE OUT BPV, WHP SHOWS 800 PSI, OFFLOAD BPV CREW & LUBRICATOR 03:30 - 03:45 0.25 CLEAN P WEXIT PJSM FOR MAKING UP NOZZLE 03:45 - 04:15 0.50 CLEAN P WEXIT MU NOZZLE ASSY AND STAB INJECTOR ON WELL 04:15 - 06:00 1.75 CLEAN P WEXIT OPEN MASTER AND PREPARE TO RIH HOLDING 800 PSI, PRESSURE BLEEDS OFF IMMEDIATELY AND WELL IS FLUID PACKED, RIH TO 8000' AND DISPLACE BACKSIDE TO GEOVIS 06:00 - 06:15 0.25 CLEAN P WEXIT CREW CHANGE. DISS OPERATIONS. MAKE RIG ROUNDS AND CHECKS. 06:15 - 07:00 0.75 CLEAN P WEXIT DISPLACE WELL TO 8.9 PPG GEOVIS MUD. TAKE WELL RTNS TO FLOW BACK TANK. FLOW CHECK WELL. 07:00 - 09:00 2.00 CLEAN P WEXIT CIRCULATE OUT OF HOLE. 09:00 - 13:00 4.00 STWHIP P WEXIT AT SURFACE. HOLD PJSM TO REVIEW DEPLOYMENT PROCEDURE. DISCUSS PROCESS STEP BY STEP. MOST HANDS NOT FAMILIAR WITH DEPLOY PROCEDURE. TOOK EXTRA TIME TO DISCUSS EACH STEP. 13:00 - 15:00 2.00 STWHIP P WEXIT RUN IN HOLE. CIRC AT MIN RATE THROUGH EDC. 15:00 - 16:30 1.50 STWHIP P WEXIT LOG INITIAL GR TIE IN TO PDC LOG FROM 7600' TO 8000'. SUBTRACT 16' CORRECTION. 16:30 - 18:00 1.50 STWHIP P WEXIT TAG PINCH POINT AT 8045'. PU BRING ON PUMPS AND MILL AHEAD FROM 8044.5'. 2200 PSI FS AT 2.49 BPM IN/OUT. DHWOB: 0.5 - 1.OK# ~1(~~.~,1~ 18:00 - 00:00 6.00 STWHIP P WEXIT TIME MILL WINDOW ~ 1'/HR, BEGIN SEEING MW ~ 8044.5', CONTINUE TIME MILLING W/ 250-350 PSI MW AND 0.8-1.5K DHWOB 12/29/2009 00:00 - 04:45 4.75 STWHIP P WEXIT CONTINUE TIME MILLING WINDOW W/ 250-300 PSI MW AND 1.5K DHWOB, WOB INCREASES TO 2.5K ~ 8051', WOB DROPS OFF TO 0.7K ~ 8051.5', CAUGHT SAMPLE ~ 8052' W/METAL, CEMENT, TRACE OF DARK SHALE & GLAUCONITE. TIME MILL TO 8053' 04:45 - 06:00 1.25 STWHIP P WEXIT MILL RATHOLE IN FORMATION FROM 8053' TO 8063' AT 4-5'/HR W/ -1.OK DHWOB AND 250 PSI MW ~ 10.0 PPG ECD. 06:00 - 06:15 0.25 STWHIP P WEXIT CREW CHANGE. DISCUSS OPERATIONS. MAKE RIG CHECKS AND ROUNDS. 06:15 - 08:45 2.50 STWHIP P WEXIT REAM WINDOW. MAKE SEVERAL PASSES. DRY DRIFT. WINDOW SMOOTH. 08:45 - 10:15 1.50 STWHIP P WEXIT OPEN EDC. CIRCULATE OUT OF HOLE. MAINTAIN 10.OPPG EMW ON BTM USING MDP EQUIPMENT AND PRESSURE SCHEDULE. 10:15 - 10:30 0.25 STWHIP P WEXIT AT SURFACE. HOLD PJSM WITH RIG CREW TO REVIEW AND DISCUSS PROCEDURE. 10:30 - 12:15 1.75 STWHIP P WEXIT PRESSURE UNDEPLOY WITH 400 PSI ON WELL. LD TOOLS. MILLS GAUGED :3.79" NO GO 12:15 - 15:30 3.25 DRILL P PROD1 MU UP BUILD BHA. (2.7 DEG MTR W/ NEW HYC RAPTOR RAZOR BIT) Printed: 1/11/2010 12:38:54 PM ~ M~- i Tree: 2 9/16", 5M Wellhead: FMC 11" x 11 ", 5M, Gen. 5 and 11" x 2 7/8" NSCT Tbg. Hnr. w/ 2.5" CIW 'H' BPV profile 113` 9-5/8" TAM Port Collar 1004' KOP @ 400' to 1965' Max. Hole Angle = 101 deg at 9094' ELr Max. PI~It:a'la Thru: 97 deg at 10259` 9-5/8", 40#/ft., L-80 BTRC 5,056' 4.5" L-(l workstring 7" 26#/ft., L-80 BTC-MOD Production Casing, (Drift ID = 6.151", cap. = 0.0383 bpf) D BTT. Ger~ II De~ Slv w/ 4" G profile: 7602' ~ Liner umm q[ 2-718" STL: 6.16#, L-80: 8397`-10549' MD 3-3116" TCI1,6.2#,L-80: 7657`-8397' MD 3-1 /2" STL,9,3#,L-80: 7614`-765T MD 3-1 /2" C}~'IS ~C ni 1e~2 812" ID} at 7624` MC D Pe ora ion ~~im arv Ref. Log: Baker Hughes MWD GRtRES 07-Jan-2010 TQL @ 7,598' ELMD .~, E i Window @ 8,040' - 8051 `ELMD _..__.._ Single Solid; cemented and perf'd ._~' 3-3/16 x 2-718" Liner. TD=10,580' ELMD ~~' A3 i"; A2 ~ ~``~-~.. DATE REV. BY COMMENTS 7/13/01 GMH Drill & Run Frac String. N-22E 06/18/06 MOR Nabors 43S ESP Completion 02/27/08 REH Nabors 3S ESP change out 1/11/10 RM/CJS CTD SIDETRACK Orig. KBEIev. = 41.5' (N22E) Orig. GLEIev. = 17.0' RT to Tbg. Spool = 27.5` (N22E) Size SPF Interval ND 2 318" 6 7987-7995 6846` - 6853' 2 718" 6 8162-8172 7003` - 7012' 2 318" 6 8162-8172 7003' - 7012' A2 2 718" 6 8191-8201 7029' - 7038' 2 318'° 6 8191-8216 7029' - 7052' All above perfs are isolated. New perfs are as follows: 9640` - 10270' ELMD(6971`-7002' TVD) 10350` - 10540' ELMD{6948`-6960' TVD Perfs were 2` PawerJet HSD; 6 SPF, 60 deg phasing, 7` x 4-112" retr=°:v dker 73t3` -112" WLEC at 7495` 7" Baker "ZXP" Packer 7494' 7" Float Collar 7594` 7" Float Shoe 7679' 4.5" Baker Flexlock Liner 7506' Hanger (tag fill @ 8201 Nabors 3S 2/27/08) 4.5" Baker Landing Collar 8317' 4.5" HES Float Collar 8361' 4.5" HES Float Shoe 8404' (PBTD) 8406' MILNE POINT UNIT WELL C-24A ~KUP) API No. 50-029-23020-01 ~~ ~ ~ ~ ~~k F ~~ (` ~ "~ ~ k ~' ~ ~ ~ ~ ~ ~s' ~~~~ { ::~~ ~i~~ ~ ~' 3~ :~µr 9,; ~~ `~ ~ ~ ~ ~ ~~° ~ ~ ~ - ~ ~ ~ ~ ~' ~ ~ ~ r~ ~ 5 k , . ~ ~ ~ ~ Y SEAN PARNELL, GOVERNOR \~_~.' ^y i~...Ij P.~ P ~~. ~,.~` n GmTM`.'Ii ~,~~°/~ ~.~.~_M t.."~..~ Y~c...avH ~..;9 ~-.., r~:°~ k~-~~~~ ~a~C~~ 1 - - - ~ ~~ ~ ~+ ~~7~ ~r~~~+ ~ ~~7~ ~iL 1'11`il l7~-.7 ~/ 333 W. 7th AVENUE, SUITE 100 COI~TSERQATIOI~T COMl-'IISSIOI~T ~;` ANCHORAGE, ALASKA 99501-3539 M~;~~~,,~.,~..,~HQAIE (907) 279-1433 4 FAX (907) 276-7542 Mr. John McMullen Engineering Team Leader BP Exploration (Alaska.), Inc. P.O. Box 196612 ~'~~.~~~~~; ~~?,,~' = ~~ ~~~i9 Anchorage, Alaska 99519-6612 ~~' ~r ~ Re: Milne Point Unit, Kuparuk River Sands, MPC-24 Sundry Number: 309-371 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval rela.ting to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the ne~ working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission deGision to Supenior Court unless rehearing has been requested. Sincerely, Daniel T. Seamvunt, Jr. ~ Chair DATED this ~ 2 day of November, 2009 Encl. ~~ ~i ~~ ~~1ALAS~IL AND GAS CON E VA ON COMMI~N ~E~G~V~C~ ~~~v ~~~~~ APPLICATION FOR SUNDRY APPROVAL ~`'' t 2o aac Zs.2so NQV 0 6 ZQO~ 1. Type of Request: a~I8SII8 OII Ht G8$ COQS. GOIYN111SS •~ Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Re-Enter Suspended~~ora e g ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Specify: ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. •~ Development ^ Exploratory 201-094 ` 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23020-00-00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPC-24 Spacing Exception Required? ^ Yes ~ No ~ 9. Property Designation; . ~ 10. Field / Pool(s): ,p~~ -~~, ~~ ADL 047434, ~25516 & 047437 Milne Point Unit / Kuparuk River_Sarr6s '~ j.~•c ~ 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): EffeCtive Depth TVD (ft): Plugs (measured): Junk (measured): 8406' • 7228' • 8298' 7127' None None Casin Len h Size M~ ND Burst Cofla Structural Conductor g2' 2" 113' 11 ' 1 9 47 Surface 027' 9- /" 50 7' 4609' S75 09 Intermediate Production 7 1' 7" 7 7' 80' 724 1 Liner 912' 4-1/2" 7494' - 840 ' 6424' - 7228' 8430 7 00 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7987' - 8216' 6846' - 7052' 2-7/8", 6.5# L-80 7107' Packers and SSSV Type: 41/2", Baker Model S3 Packers and SSSV 7402' / 6347' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ~ Description Summary of Proposal ^ BOP Sketch ^ Exploratory ~ Development ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: November 20, 2009 ' ^ Oil ^ Gas ^ WDSPL ^ GSTOR ~ Abandoned 16. Verbal Approval: Date: ^ WINJ ^ GINJ ^ WAG ^ Plugged ^ SPLUG Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLau hlin 564-4387 Printed Name Jo Mc len Title Engineering Team Leader Prepared By Name/Number. 564-4628 ' Terrie Hubble ~ , j Signature Phone 564-4711 Date j ~ Commission Us~ ~nl Conditions of approva l: Notify Commission so that a representative may witness Sund Number: '~ '3 7 ~ ry ^ Plug Integrity L1~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance x3~~~ ~~~ /~P `-T~sfi ~ Other: ~.~ 2 J C~ ~ ~J S ~ ~ ri ~~ ~ S~~~""~ j~ .~ b/C.e-IL ~S (' C~ ~Ctt 1"vr ~~1' Subsequent Form Required: / ~ ,_ ~Q"~ / APPROVED BY / / ~ r Approved By: COMMISSIONER THE COMMISSION Date ~ Form 1 03 Revised dflZ000 O Novis~ ~~~~~~~A~ ~~ ~~y-D~ ~~ Submit In Duplicate ..~ ~~. ~ ~'~ ,~ ~~/~'/~f 01~ ~ . To: Tom Maunder Petroleum Engineer bp Alaska Oil & Gas Conservation Commission From: Sean McLaughlin CTD Engineer Date: November 4, 2009 Re: Milne Point C-24 Sundry Approval Sundry approval is requested to abandon perforations on well MPC-24 in preparation for a CTD sidetrack. MPC-24 was drilled 7/13/01 and completed as a A2/A3/C sand KUP producer. The A sands were fraced in August-2001 with 180,000 # of 16/20 carbolite. 2 ESP's were RIH before the 3rd one finally ran for a• substantial amount of time (Oct-01). The well has had 2 additional ESP's since the Oct-01 pump including the ~ current pump installed on 3-15-08. The well is currently online making low oil rate and high water cut. MPC-24A will be drilled to a more optimum location. The sidetrack, MPC-24A, is scheduled to be drilled by Nordic 2 starting January 10, 2010 using the managed pressure drilling technique. This horizontal lateral will target Kuparuk A2 and A3 reserves to capture currently . nonrecoverable resources. The perforations in the parent well will be abandoned with cement downsqueezed past the whipstock. The sidetrack lateral will exit the parent well at 8,040' md in the B shale and drill a--2480' • lateral to a TD of 10,520' md. The sidetrack will be completed with a solid, cemented and perforated 3-3/16" x 2-7/8" liner. The following describes work planned. A schematic diagram of the proposed sidetrack is attached for reference. ~~o~a,fed ~( .v,'// ~fr0~ 7'pkr `Gb~:-~ y~O h'- O~ c~ C,jfwj~ h~+cc // ~~v~ n~w~ vtn~'ca/ Tv r~~/s~;y ~fo~.'so,r4~, ~,~,f f~foala~ :~-Pro~e r~to~r~Y' ,~~ rti~ r po rr~~a.- o. T~e ~: •oi.~ i~'~ ~~~~~of CTD Sidetrack Summarv Prior to drilling operations a workover rig will lay down the ESP completion, pull the 4-1/2" x 7' packer, and run a 4-1/2" workstring. After the coil drilling unit is rigged down the workover rig will return to pull the kill string and rerun the ESP completion. Nabors 4ES RWO operations: The RWO is slated to beain about November 20. 2009. 1. MIRU. Test BOPE to 3500 psi. 2. Kill Well 3. Pull 2-7/8" ESP completion 4. Mill / Fish 4-1 /2" x 7" packer 5. Perform a scraper run in the 7" csg to the top of the 4-1/2" liner 6. RIH with 7" test packer. Test 7" csg integrity to 2000 psi. 7. Run 4-1/2" workstring with a 7" retrievable pkr and PBR. 8. RDMO to allow Nordic II to sidetrack well Pre-CT Rig Work: The pre CTD work is slated to begin immediatelv following the RWO. 1. Pull ball and rod 2. Pull RHC sleeve 3. Run dummy WS drift to 8,100' 4. Set Baker whipstock at 8,040' ~ 5. Downsqueeze cement past whipstock, 16 bbls of 15.8 ppg cement S~` 6. Extend pad with an ice apron ~ 7. Bleed, remove, and blind flowlines '~j0~ ~ 3~ 8. Drill mousehole extension Rig Sidetrack Operations: (Scheduled to begin on January 10, 2010 using Nordic rig 2) 1. MIRU Nordic Rig 2 2. NU Zi/16" CT Drillina BOPE and test. 3. Mill 3.8" window in 4-1/2" liner from mechanical whipstock set at 8,040'. 4. Drill build section with 4-1/8" bicenter bit, and land well in target A sand. 5. Drill lateral section to 10,520'. 6. Flow check well and lay in KWF as needed. 7. Run and cement a 3-3/16" x 2-3/8" L-80 liner string. Expect ~30 bbl of 15.8 ppg cement ~.~~ 8. Cleanout and log liner with a memory SWS GR-CCL logging tool. ~ • . 9. Perforate well. 10. Circulate well to KWF brine. FP well to 2000'. 11. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 12. RDMO Nordic 2. Nabors 4ES RWO operations: The RWO is slated to bepin after the sidetrack. 1. MIRU after Nordic II finishes 2. Test BOPE to 3500 psi. 3. Release packer and pull 4-1/2" workstring 4. Run new ESP on 2-7/8" tubing 5. RDMO Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. Sean McLaughlin CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble Tree: 2 9/16", 5M ~ M P C-~~t lev. = 41.5~ (N22E) Wellhead: FMC 11" x 11", 5 ~lev. = 17.0~ and 11" X 2 7/8" NSCT Tbg. Hnr. w/ I I I I I I RT to T g. Spool = 27.5' (N22E) 2.5" CIW 'H' BPV profile 113' 9-5/8" TAM Port Collar 1004` KOP ~ 400' to 1965` Max. Hole Angle = 56.32 deg. Max. Hole Angle Thru Perfs. _+30 deg. 9-5/8", 40#/ft., L-80 BTRC 5,056` 2 7/8" 6.5 ppf, L-80 S rd EUE tubing (dritt ID = 2.347", cap = 0.00592 bpf) 7" 26#/ft., L-80 BTC-MOD Production Casing, (Drift ID = 6.151", cap. = 0.0383 bp~ ,I~t Cut 4.5" h~lnp vW 7~g ~ bazooka top 4.5" Bak~ Modol "S-3" Pkr. 7,402' 4.S" HES "XN" nlpple " 7 415' (No-Qo ID = 3.725 ) . WLEG 7,426' 7" Baker "ZXP" Packer 7494' 7" Float Collar 7594' 7" Float Shoe 7679' 4.5" Baker Fiexlock Liner 7506' Hanger (tag fill @ 8201 Nabors 3S 2/27/OS) 4.5" Baker Landing Collar 8317' 4.5" HES Float Collar 8361` 4.5" HES Float Shoe 8404` (PBTD) 8406' ~ DATE REV. BY COMMENTS 7/13/01 GMH Drill & Run Frac String. N-22E 10/5/01 GMH Nabors 4ES ESP Completion 06/18/06 MOR Nabors 43S ESP Completion 02/27/08 REH Nabors 3S ESP change out Camco 2-7/8" x 1" 142` sidepocket KBMM GLM Camco 2-7/8" x 1" 2029' sidepocket KBMM GLM Camco 2-7/8" x 1" 6852' sidepocket KBMM GLM 2-7/8" XN nipple 6999' (ID 2.205") Tandem Pump, 18P75 SXD 160P11 SSD 7042~ Tandem Gas Separator 7070~ GRSFTX AR H6 Tandem Seal Section ~ Model GSB3DB LT/UT SB/S8 PFSA/FSACLS 7075 Motor, 152 HP, 2325 volt, 7088~ 40 amp, Model KMH Pumpmate 7102' w/ 5 Fin Centralizer MILNE P~INT UNIT WELL C-24 (KUP) API No_ 50-029-2~020 BP EXPLORATION ~AK~ MPC-24A Propos~TD sidetrack - Single Cer ~ Liner Tree: 2 9/16", 5M Orig. KBEIev. = 41.5' (N22E) Wellhead: FMC 11" x 11", 5M, Gen. 5 Orig. GLEIev. = 17.0~ RT to Tbg. Spool = 27.5' (N22E) and 11" x 2 7/8" NSCT Tbg. Hnr. w/ 2.5" CIW 'H' BPV profile ~~ 3~ 9-5/8" TAM Port Collar 1004' KOP @ 400' to 1965' Max. Hole Angle = 56.32 deg. Max. PlortfsPcflglBQfdl~g. 9-5/8", 40#/ft., L-80 BTRC 5,056' 4.5" L-80 workstring 7" 26#/ft., L-80 BTC-MO~ Production Casing, (Drift ID = 6.151", cap. = 0.0383 bp~ 179,534 # 16/20 carbolite behind pipe 8/4/01 TOL @ 7,700' ~ ~ i Single Solid, cemented and perf'd 3-3/16 x 2-7/8" Liner 27 deg 7' x 4-1l2" retrievable packer @ 7400' TD=10,520' • ~ A3 A2 s Window @ 8,040'~ DATE REV. BY COMMENTS 7/13/01 GMH Drill 8~ Run Frac String. N-22E 06/18/06 MOR Nabors 43S ESP Completion 02/27/08 REH Nabors 3S ESP change out 6/25/09 MSE PROPOSED CTD SIDETRACK Size SPF Interval ND 2 318" 6 7987-7995 6846' - 6853' 2 718" 6 8162-8172 7003' - 7012' 2 318" 6 8162-8172 7003' -1012' A2 2 718" 6 8191-8201 7029' - 7038' 2 318" 6 8191-8216 7029' - 7052' 7" Baker "ZXP" Packer 7494' 7" Float Collar 7594' 7" Float Shoe 7679' 4.5" Baker Flexlack Liner 7506' Hanger (tag fill @ 8201 Nabors 3S 2/27/OS) 4.5" Baker Landing Collar 8317' 4.5" HES Float Collar 8361 ` 4.5" HES Float Shoe 8404' (PBTD) 8406` STATE OF ALASKA ' -/-Oa? R~~~I1/~® ALA OIL AND GAS CONSERVATION COM ON REP OF SUNDRY WELL OPERATIONS MAR 2 ~ 2008 1. Operations Performed: ~~ ~ & ~ ~. CDCI'ttn ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-E~ded Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other Change Out ESP ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 201-094 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23020-00-00 ~' 7. KB Elevation (ft): 44.80'c 9. Well Name and Number: MPC-24 ~' 8. Property Designation: 10. Field /Pool(s): ADL 047437 f Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 8406 ~ feet true vertical 7228 , feet Plugs (measured) N/A Effective depth: measured 8298 feet Junk (measured) N/A true vertical 7127 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 20" 113' 113' 1490 470 Surface 5027' 9-5/8" 5057' 4609' 5750 3090 Intermediate Production 7651' 7" 7679' 6580' 7240 5410 Liner 912' 4-1/2" 7494' - 8406' 6424' - 7228' 8430 7500 ~~~ ~~~ ~ z~ ~~~ Perforation Depth MD (ft): 7987' - 8216' Perforation Depth TVD (ft): 6846' - 7052' 2-7/8", 6.5# L-80 7107' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 4-1/2", Baker Model S3 7402' 7" Baker ZXP Packer 7494' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and fin al pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 1340 0 Subsequent to operation: 66 102 172 270 189 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Sean McLaughlin,~5ti4-4387 N/A Printed Name Sondra te 1 ~__ _ ~ Title Drilling Technologist r Prepared By Name/Number: ' Si nature Phone 564-4750 Dat ~~~ Sondra Stewman 564-4750 Form 10-404 Revised 04/2006 r,':°' `6$ ~~s-- ;~:~1F r ) jQQ~ Submit Original Only ~~ ~~ Tree: 2 9/16", 5M M P C -24 KB Elev. = 41.5` (N22E) Wellhead: FMC 11 " x 11 ", 5~en. 5 RT to Tbg.ISpooll?27.5` (N22E) and 11" x 2 7/8" NSCT Tbg. Hnr. w/ I I I I I I 2.5" CIW 'H' BPV profile 113' 9-5/8" TAM Port Collar 1004' KOP @ 400' to 1965` Max. Hole Angle = 56.32 deg. Max. Hole Angle Thru Perfs. _ +30 deg. 9-5/8", 40#/ft., L-80 BTRC 5,056' 2 7/8" 6.5 ppf, L-80 8 rd EUE tubing (drift ID = 2.347", cap = 0.00592 bpf) 7" 26#/ft., L-80 BTC-MOD Production Casing, (Drift ID = 6.151", cap. = 0.0383 bpf) Camco 2-7/8" x 1" 142' sidepocket KBMM GLM Camco 2-7/8" x 1" 2029' sidepocket KBMM GLM Camco 2-7/8" x 1" 6852' sidepocket KBMM GLM 2-7/8" XN nipple 6999' (ID 2.205") Tandem Pump, 18P75 SXD 160P11 SSD 7042` Tandem Gas Separator 7070' GRSFTX AR H6 Tandem Seal Section Model GSB3DB LT/UT SB/SB PFSA/FSACL5 7075` Motor, 152 HP, 2325 volt, 7088` 40 amp, Model KMH Stimulation Summary Pumpmate 7102` 179,534 # 16/20 carbolite behind pipe ~ w/ 5 Fin Centralizer 8/4/01 Size SPF Interval ND 2 318" 6 7987-7995 6846` - 6853' 2 2 718" 6 8172 816 7003` - 7012' 2 318" 6 -8172 8162 7003' - 7012' nn f'tL 2 718" 6 8191-8201 7029` - 7038' 2 318" 6 8191-8216 7029' - 7052' DATE REV. BY COMMENTS 7/13/01 GMH Drill & Run Frac String. N-22E 10/5/01 GMH Nabors 4ES ESP Completion 06/18/06 MOR Nabors 43S ESP Completion 02/27/08 REH Nabors 3S ESP change out Jet Cut 4.5" tubing w/ 7396' bazooka top ` 4.5" Baker Model "S-3" Pkr. 7,402 4.5" HES "XN" nipple N ID 3 725" -G 7,415 ( o = . o ) W LEG 7,426` 7" Baker "ZXP" Packer 7494' 7" Float Collar 7594' 7" Float Shoe 7679' 4.5" Baker Flexlock Liner 7506` Hanger (tag fill @ 8201 Nabors 3S 2/27/08) 4.5" Baker Landing Collar 8317` 4.5" HES Float Collar 8361' 4.5" HES Float Shoe 8404` (PBTD) 8406` MILNE POINT UNIT WELL C-24 (KUP) API No. 50-029-23020 BP EXPLORATION (AK) • • BP EXPLORATION Page 1 of 3 Operations Summary Report Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: WORKOVER Start: 2/23/2008 End: 2/27/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/27/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/22/2oos 118:00 - oo:oo I s.oo I MOB 12/23/2008 100:00 - 11:00 I 11.00 I MOB I P 11:00 - 22:00 I 11.001 RIGU I P 22:00 - 00:00 I 2.001 KILL I P 12/24/2008 100:00 - 04:00 4.00 KILL P 04:00 - 06:00 2.001 KILL P 06:00 - 07:00 1.00 I KILL P 07:00 - 08:00 1.00 (KILL P 08:00 - 09:00 I 1.001 KILL I P 09:00 - 11:00 I 2.001 KILL I P 11:00 - 12:30 1.50 KILL P 12:30 - 14:00 1.50 KILL P 14:00 - 15:30 I 1.501 WHSUR I P 15:30 - 21:00 I 5.50 I W HSU R I P 21:00 - 21:30 0.50 BOPSU~ P 21:30 - 22:00 0.50 BOPSU P PRE Rig released from MPE-04 ~ 18:00 hours. Prep for rig move to MPC-24. Sustained high winds preventing lowering of Derrick. PRE Lower Derrick C~ 03:00. Winds finally subside below 25 MPH. Prep for Rig Move. MPU roads and pads clean and clear spine road and access road to C pad. Arrive on location on C-pad ~ 11:00. PRE Notify AOGCC about impending BOPE test. Chuck Scheve waived State's right to witness. Spot BOPE behind wellhouse. Align carrier to well. Lay out matting boards and Herculite. Position carrier, pipe shed, pit modules. Connect components, raise and scope Derrick, assemble handi berm spill containment. R/U Geronimo line, Put stairs and handrails in place DECOMP R/U to tree to kill well. IA valves on wellhead are not holding. Called well support techs. R/U and serviced IA valves. Continue to hook up line to tiger tank. DECOMP Well support techs serviced IA valves. R/U secondary annulus valve. Test surface lines to 3,500 psi, warm return line to tiger tank and test to 500 psi. Blow lines down. DECOMP R/U Lubricator and pull 2-1/2" Type H BPV. 1,380 psi on tubing, 1,380 psi on IA and 40 psi on OA. UD Lubricator. DECOMP Crew change. Double check rig up, choke alignment. PJSM with crew and vac truck drivers. DECOMP Bleed gas from IA through choke to Tiger Tank. Bleed to 500 psi. Come online w/ pump and SW down Tbg. Discharge line from pump leaking at connection to Micro-Motion. Shut down, blow down. Tighten connection. DECOMP T / IA / OA - 1280 / 580 / 40 psi. Pump SW down Tbg ~ 4 BPM, catch fluid after 20 Bbls pumped. Gas only returns. Pump 50 Bbls w/ no fluid returns (gas only), close choke and Bullhead 50 Bbls into formation C~ 3.5 BPM, 380 psi. Shut down and check tubing pressure. Tbg - 0 psi, IA - 390 psi. DECOMP Circulation kill by pumping SW down Tbg ~ 4 BPM, 580 psi. IA pressure from 380 psi to 0 psi. Gas and crude in returns. After 230 Bbls pumped, SW returns. ,Puma total of 325 Bbls w/ 160 Bbls returns. 50% losses .Tubing and IA to 0 psi. DECOMP Bullhead SW down IA ~ 4 BPM, 460 psi. Catch fluid after pumping 30 Bbls. Bullhead 200 Bbls down IA. Flnal rate of 4 BPM ~ 960 psi. DECOMP Flowcheck well for 30 minutes. Tbg and IA on vacuum. Dry rod TWC. Measure T-bar for 1 9/16" to engage C in hanger profile. Bullhead 100 Bbls down IA C~ 3.5 BPM and injection pressure of 850 psi for 30 minutes (charted) to check TWC. Pressure test TWC from above to 3500 psi for 30 min. and chart. DECOMP ND Tree. Check 2 7/8" hanger threads by screwing in XO w/ 8 turns. DECOMP NU DSA. PU BOPE from cradle, place onto wellhead and NU BOPE. Install riser and hook up hydraulic lines to stack. Gravity feed 30 Bbl of SW to IA every hour. DECOMP Function test BOPE. DECOMP R/U to PE fill BOP stack and choke manifold. M/U test Printed: 3/72/2008 11:43:48 AM • BP EXPLORATION Operations Summary Report Page 2 of 3 Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: WORKOVER Start: 2/23/2008 End: 2/27/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/27/2008 Rig Name: NABOBS 3S Rig Number: i I I I Date ~ From - To Hours Task Code NPT Phase Description of Operations 2/24/2008 21:30 - 22:00 0.50 BOPSU P DECOMP assembly. 22:00 - 00:00 2.00 BOPSU P DECOMP Test BOPE, annular preventor, pipe rams, blind rams, Kill line valve, chike line valves, choke manifold valves, and floor valves to 250 psi low and 3,500 psi high pressures. Each test was held for 5 minutes. No failures. AOGCC witness of BOP test was waived by Chuck Scheve 2/25/2008 00:00 - 02:30 2.50 BOPSU P DECOMP Test BOPE, annular preventor, pipe rams, blind rams, Kill line valve, chike line valves, choke manifold valves, and floor valves to 250 psi low and 3,500 psi high pressures. Each test was held for 5 minutes. Perform Koomey drawdown test. No failures. AOGCC witness of BOP test was waived by Chuck 02:30 - 03:30 I 1.00 I BOPSUR P 03:30 - 05:00 1.~0 ~ WHSUR P 05:00 - 06:00 I 1.001 PULL I P 06:00 - 08:30 I 2.501 PULL I P 08:30 - 16:00 I 7.501 PULL I P 16:00 - 20:00 I 4.001 PULL I P 20:00 - 20:30 ~ 0.501 PULL P 20:30 - 21:30 1.00 PULL P 21:30 - 22:00 0.50 CLEAN P 22:00 - 00:00 2.00 CLEAN P 2/26/2008 100:00 - 02:30 I 2.50 I CLEAN I P 02:30 - 06:00 I 3.50 I CLEAN I P DECOMP Break down test assembly, blow down lines and choke manifold. DECOMP M/U Opso Lopso and R/U well support lubricator. Test lubricator to 500 psi. Pull 2-1/2" Type H TWC. R/D lubricator, L/D Opso Lopso. Tubing is on a Vac. DECOMP M/U landing joint with TIW valve. Screw into hanger and back out lock down screws. DECOMP PU hanger w/ 64K PUW. Pull up into stack. Attempt to load well w/ 60 Bbls of SW. No returns. Tubing and IA on Vacuum. Break out and lay down tubing hanger. load IA w/ 1/2 BPM SW as rig up to pull completion. Shut down charge pump and flow check well for 30 minutes. Shoot FL in Tbg (tubing on vacuum, fluid level falling from 600' . Run cable over shieve to spoo er. rou es oot hydraulics on spooler (-40 deg F). DECOMP POH w/ 2 7/8" ESP completion, standing tubing back in Derrick. Continuous hole fill ~ 1/2 BPM, no returns. Laid down 3 singles, stood back 108 stands. DECOMP BOLD ESP Assembly. Recovered: 118 LaSalle Clamps, 3 Armsterguards, 6 protectolators. Continuous hole fill ~ 1/2 BPM w/ no returns. No sign of scale of fill in pump. DECOMP UD containment trunk for ESP cable. R/D tubing handling equipment. DECOMP Clear rig floor of ESP equipment and clean rig floor. DECOMP Inspect and service drawworks, blocks and crown sheaves. DECOMP M/U 2-7/8" PAC muleshoe and P/U 2-7/8" PAC DP from pipeshed. Continuous hole fill ~ 1/2 bpm. DECOMP P/U 2-7/8" PAC DP from pipeshed to 1,010'. Continuous hole fill ~ 1/2 bpm. DECOMP RIH with 2-7/8" tubing from derrick from 1,010'to 7,357'. Obtain parameters, 55,000 up weight, 45,000# down weight. Slack off through tubing stub at 7,396', did not see tubing stub. 06:00 - 07:00 1.00 CLEAN P DECOMP PU singles from pipe shed. RIH and tag fill ~ 8201'. Confirm tag depth. 07:00 - 11:30 4.50 CLEAN P DECOMP POH laying down 9 singles of 2 7/8" tubing which was used for tag of fill ~ 8201'. POH standing back 108 stds of 2 7/8" tubing in derrick, for completion. Continuous hole fill ~ 1/2 BPM (no returns). 11:30 - 13:00 1.50 CLEAN P DECOMP BOLD 33 jts of 2 7/8" PAC DP. Printed: 3/12/2008 11:43:48 AM u BP EXPLORATION Page 3 of 3 Operations Summary Report Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: WORKOVER Start: 2/23/2008 End: 2/27/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/27/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours .Task Code NPT Phase Description of Operations 2/26/2008 13:00 - 14:30 1.50 BUNCO RUNCMP Clean and clear rig floor. Prep for PUMU ESP Assembly. 14:30 - 17:30 3.00 BUNCO RUNCMP PUMU ESP Assembly. Continuous hole fill f~ 1/2 BPM (no returns . Check ESP cable - OK. 17:30 - 00:00 6.50 BUNCO RUNCMP R1H w/ ESP Assembly on 2 7/8" Tubing. 1 XN, 3 GLM's. Check conductivity of ESP cable every 2,000', fill tubing and flush pump with 10 bbls of seawater. Continuous hole fill ~ 1/2 BPM (no returns). 2/27/2008 00:00 - 02:30 2.50 BUNCO RUNCMP Continue RIH w/ ESP completion assembly on 2-7/8" tubing from derrick, Total joints ran = 219 jts, 118 LaSalle clamps, 6 protectolizers, 3 flat guards. Continuous hole fill) ~ 30 BPH (no returns) 02:30 - 03:30 1.00 BUNCO RUNCMP PU/MU tubing hanger with penetrator(FMC rep) 03:30 - 06:00 2.50 BUNCO RUNCMP MU ESP penetrator splice (Centrilift rep). Final checks - OK. PUW 60K, SOW 50K. Land tubing hanger, RILDS. 06:00 - 08:00 2.00 BUNCO RUNCMP Dry rod TWC. Test from below by pumping SW ~ 3 1/2 BPM, caught fluid after pumping 30 Bbls, final injection pressure of 810 psi. Total of 105 Bls SW pumped. Test TWC to 1000 psi for 30 minutes. Both test charted. 08:00 - 14:00 6.00 BUNCO RUNCMP Remove ESP shieve from Derrick for inspection ~ Tuboscope. Change rams in BOPE from 2 7/8" fixed to 2 7/8" x 5" VBR's_ . ND BOPE. 14:00 - 17:00 3.00 BUNCO RUNCMP NU Tree. Centrilift final checks: 2528 psi at intake /135 deg F motor temp / 3.4 ohms phase to phase / 1.2 gig ohms phase to ground. Test hanger void to 5000 psi for 30 minutes. Test tree w/ diesel to 5000 psi and chart for 5 minutes. No visible leaks. 17:00 - 18:00 1.00 BUNCO RUNCMP Psi test lubricator to 500 psi, pull TWC. Dry rod BPV. Normal up tree and cellar. Final tbg press=0, IA=O, OA=40 psi, Rig released C~3 18:00 hrs 2/27/08 Printed: 3/12/2008 11:43:48 AM STATE OF ALASKA ~~'~ ~~ ALASKA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS ~,E(M~/G~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate Q Other Performed: Alter Casing ~ Pull Tubing ~] Perforate New Pool ~ Waiver ~ Time Ext~i~n Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5 - I ^ - Name: Development Exploratory ~' AtiE~Ut8~8 - ._. __ . 3. Address: P.O. Box 196612 Stratigraphic SBrVICe ' 6• API Number: Anchorage, AK 99519-6612 50-029-23020-00-00 7. KB Elevation (ft): 9. Well Name and Number: 44.8 KB MPC-24 8. Property Designation: 10. Field/Pool(s): ADLO-047437 ' MILNE POINT Field! KUPARUK RIVER OIL Pool 11. Present Well Condition Summary: Total Depth measured 8407 feet Plugs (measured) None true vertical 7228.47 - feet Junk (measured) None Effective Depth measured 8298 feet ~ ~ ; n~~p/ ' ~r true vertical 7127 feet v'~" Casing Length Size MD TVD Burst Collapse Conductor 82' 20" Surface - 113' Surface - 113' Surface 5027' 9-518" 40# L-80 Surface - 5057' Surface - 4609' 5750 3090 Production 7651' 7" 26# L-80 Surface - 7679' Surface - 6580' 7240 5410 Liner 912' 4-1 /2" 12.6# L-80 7494' - 8406' 6424' - 7228' 8430 7500 Perforation depth: Measured depth: 7987 - 7995 8162 - 8172 8191 - 8201 8201 - 8216 True Vertical depth: 6846.48 - 6853.53 7002.72 - 7011.78 7029.05 - 7038.15 7038.15 - 7051.84 Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 SURFACE - 7111' 0 0 - Packers and SSSV (type and measured depth) 4-1/2" BAK~ERp~S3 ~} 7402' ~ ~~~7 ' " ~~~ NOV 1 ,. 7494 7 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): R.J ~ ~(~~1 ~ ~~U~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 39 18 62 192 Subsequent to operation: 39 18 56 198 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory !"`,, Development ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas WAG ~' GINJ WINJ ~ WDSPL ~' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature ~ Phone 564-4944 Date 11/9/2007 Form 10-404 Revised 04/2006 ~ 1h. J`~ Submit Original Only • • MPC-24 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~TIVITYDATE ..SUMMARY 1 11/1/2007 (Acid treatment) T/I/0=550/470/80. Spear into tbg w/ 17 bbls crude for infectivity ', followed by 15 bbls 10% DAD acid. Spot acid on ESP w/ 35 bbls crude. Saw acid '. @ ESP w/ 15 bbls crude pumped away. Let soak for 20 minutes. Run ESP in ', =:forward & reverse. Shutdown ESP. Pump 100 bbls crude down tbg for. overdisplacement. FWHP=700/540/80. FLUIDS PUMPED BBLS 15 10% DAD ACID 3 60/40 METH 152 CRUDE 170 TOTAL G/Ì' . STATE OF ALASKA ; (fJJ 6.-6 ALAAOILANDGASCONSERVAT,ONCOMa,ON jUL 142006 REPORT OF SUNDRY WELL OPERA TIONR'a ka 0" & G C C " ì\ S I as ons. ommlsslon RECEIVED . 1. Operations Performed: ... o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver 181 Other o Change Approved Program o Operation Shutdown 181 Perforate o Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 201-094 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23020-00-00 7. KB Elevation (ft): 44.80' 9. Well Name and Number: MPC-24 8. Property Designation: 10. Field 1 Pool(s): ADL 047437 Milne Point Unit 1 Kuparuk River Sands 11. Present well condition summary Total depth: measured 8406 feet true vertical 7228 feet Plugs (measured) N/A Effective depth: measured 8298 feet Junk (measured) N/A true vertical 7127 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 20" 113' 113' Surface 5027' 9-518" 5057' 4609' 5750 3090 Intermediate Production 7651' 7" 7679' 6580' 7240 5410 Liner 912' 4-1/2" 7494' - 8406' 6424' - 7228' 8430 7500 ",' Y'l,,-ìr..¡ :;;~' F ¡..:. .¡.~ ~ Perforation Depth MD (ft): 7987' - 8216' Perforation Depth TVD (ft): 6846' - 7052' 2-7/8",6.5# L-80 7111' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 4-1/2", Baker Model S3 7402' 7" Baker ZXP Packer 7494' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: o Exploratory 181 Development o Service 181 Daily Report of Well Operations 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman Title Technical Assistant .~~("'. lJ= / '"""- Prepared By Name/Number: SI9IJ~ture ,'\' ~é''^-¥'';L/--':'" ;~ - Phone 564-4750 Date L :} \ LID (~ondra Stewman, 564-4750 . . Form 10-404 Revised 04/2006 OR \ G \ N A L ;;::~;'''''''-'''^'RBDMS BFL JUl ¡ 4 1006 Submit Onglnal Only Tree: 29/16", 5M Wellhead: FMC 11" x 11", 5.n. 5 and 11" x 2 7/8" NSCT Tbg. Hnr. wI J 2.5" CIW 'H' BPV profile 113' I 9-5/8" TAM Port Collar 1004' KOP @ 400' to 1965' Max. Hole Angle = 56.32 deg. Max. Hole Angle Thru Perfs. = +30 deg. 9-5/8", 40#/ft., L-80 BTRC I 5,056' l Oa<B Elev. = 41.5' (N22E) ~L Elev. = 17.0' RT to Tbg. Spool = 27.5' (N22E) Camco 2-7/8" x 1" sidepocket KBMM GLM I 143' I Cameo 2-7/8" x 1" sidepocket KBMM GLM I 2030' I Cameo 2-7/8" x 1" sidepoeket KBMM GLM 16853' I 2-7/8" XN nipple I 7000'1 (ID 2.20S") 2 7/8" 6.5 ppf, L-BO B rd EUE tubing (drift 10 = 2.347", cap = 0.00592 bpf) 7" 26#/ft., L-80 BTC-MOD Production Casing, (Drift ID = 6.151", cap. = 0.0383 bpf) Triple Tandem Pump, 160 Stg. I 7043' I tandem 538P11 SSD 1:1 & 18 Stg. 538P75 SXD Tandem Gas Separator I 7067' I GRSFTX AR H6 Tandem Seal Section I 7072' I Model GSB3DB UT/L T IL H6 PFS AB HSN Motor, 165 HP, 2385 volt, I 7086'1 53 amp, Model KMH Stimulation Summary Phoenix MS1 I 7109'1 wI 5 Fin Centralizer 179,534 # 16/20 carbolite behind pipe 8/4/01 Perforation Summary Jet Cut 4.5" tubing wI 7396' Ref Loo CCLlGR 08/03/01 bazooka top 4.5" Baker Model "8-3" Pkr. 7,402' Size SPF Interval 4.5" HES "XN" nipple 7,415' (No-Go ID = 3.725") WLEG 7,426' 2 3/8" 6 7987-7995 7" Baker "ZXP· Packer 7494' A3 7" Float Collar 7594' 27/8" 6 8162-8172 7003'·7012' 7" Float Shoe 7679' 2 318" 6 8162·8172 7003'·7012' 4.5" Baker Flexlock Liner 7506' A2 Hanger 27/8" 6 8191-8201 7029' - 7038' 4.5" Baker Landing Collar 8317' 23/8" 6 8191-8216 7029' - 7052' 4.5" HES Float Collar 8361' 4.5" HES Float Shoe 8404' (PBTD) 8406' DATE 7/13/01 10/5/01 06/18/06 REV. BY GMH GMH MOR COMMENTS Drill & Run Frac String. N-22E Nabors 4ES ESP Completion Nabors 43S ESP Completion MILNE POINT UNIT WELL C-24 (KUP) API No_ 50-029-23020 BP EXPLORATION (AK) e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-24 MPC-24 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 6/5/2006 Rig Release: 6/17/2006 Rig Number: N3S Spud Date: 7/13/2001 End: 6/17/2006 6/5/2006 00:00 - 00:00 24.00 MOB N RREP PRE Transfer Case on Rig Carrier failed. Rig Carrier is being repaired on MPL-pad and remainder of rig components are on MPC-pad. Pulled the transfer case out at 1500-hours. 6/6/2006 00:00 - 07:15 7.25 MOB N RREP PRE Transfer Case on Rig Carrier failed. Rig Carrier is being repaired on MPL-pad and remainder of rig components are on MPC-pad. Putting drive train back together at 0600-hrs. Begin moving Rig Carrier from MPL-pad @ 0715-hours. 07:15 - 08:15 1.00 MOB P PRE Move Rig Carrier to MPC-24. 08:15 - 19:30 11.25 RIGU P PRE Layout plywood and rig mats around Tree in preparation for lining up rig over tree. 011 leaked to pad from Pitcher Nipple while rig was being lined up to well. Please see Remarks. Rig up Pipe Shed and Mud Pits. Hookup remaining piping and equipment that was removed for the transfer case drive hub repair. 19:30 - 00:00 4.50 RIGU P PRE RIU Vac Trucks and take on 1200 F seawater to Pits. H/U hardline to Tiger Tank and test with air. Check all circulating lines. Actuate SSV with Porta-Power pump, install Fusible Cap, bleed off actuator pressure. P/U Lubricator and pull BPV. Casing pressure = 940-psi and Tubing pressure = 800-psi. Hold PJSM for circulating out diesel freeze protect. Rig accept @ 2200 hrs. 6m2006 00:00 - 03:00 3.00 RIGU P PRE RIU Vac Trucks and take on 1200 F seawater to Pits. H/U hardline to Tiger Tank and test with air. Check all circulating lines. Actuate SSV with Porta-Power pump, install Fusible Cap, bleed off actuator pressure. P/U Lubricator and pull BPV. Casing pressure = 940-psi and Tubing pressure = 800-psi. Hold PJSM for circulating out diesel freeze protect. Rig accept @ 2200 hrs. 01 :00 - 02:30 1.50 PULL P DECOMP Bleed Tubing from 800 psi to 100 psi. Bleed IA from 940 psi to 100 psi. 02:30 - 06:00 3.50 KILL P DECOMP Reverse Circulate 10 Bbls from Tubing to Tiger Tank. Mud Pump failed. Begin troubleshooting. . 06:00 - 12:30 6.50 KILL N RREP DECOMP Troubleshoot Mud Pump throttle and clutch problems and repair same. Note: while working on Mud Pump problems, we bled off the tubing to 30-40 psi within 1-minute of cracking the choke; climbed to 330-psi by 1230-hours. 12:30 - 13:30 1.00 KILL N DECOMP Reverse Circulate tubing volume, 44-Bbls at 3-1/2 BPM from 570-psi to 800-psi. S/I and realign valves to circulate down tubing. 13:30 - 15:00 1.50 KILL N DECOMP Start circulating by bull heading down tubing. Stop bullheading at 5-Bbls with 1380-psi Tubing and 1580-psi Casing. S/I for 1 O-minutes and pressures drop to 730-psi Tubing and 930-psi Casing. Open annulus and start pumping down Tubing for 218-Bbls @ 3-1/2 BPM, 830-psi tubing, 320-psi Casing. S/I to take on seawater to pits. Haul 290-Bbls from Tiger Tank. While S/I, the well equalized to 330-psi, both sides. 15:00 - 22:00 7.00 KILL N DECOMP Resume pumping and pump 218-Bbls and Tiger Tank level alarm sounds so S/I and gage tank. Tiger Tank has 470-Bbls of fluid. S/I well and monitor pressures. Pressures quickly equalize to 480-psi, then build to 650-psi Tubing and 680-psi Casing. Calculate new kill weight fluid of 10.6-ppg. Call for 290-Bbls of 10.4-ppg brine and additional100-Bbls of heavy NaBr Spiking fluid capable of increasing brine weight to Printed: 6/20/2006 12:16:15 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-24 MPC-24 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 6/5/2006 Rig Release: 6/17/2006 Rig Number: N3S Spud Date: 7/13/2001 End: 6/17/2006 6/7/2006 15:00 - 22:00 7.00 KILL N DECOMP 10.8-ppg. As of 2200-hrs, pressures increased to 7oa-psi Tubing and 760-psi Casing and has equalized. 22:00 - 00:00 2.00 KILL N DECOMP Empty Tiger Tank and Pits. 6/8/2006 00:00 - 09:30 9.50 KILL P DECOMP Circulate 41 Bbls of 10.4 ppg brine while holding 700 psi on lA, taking returns to the Tiger Tank. Circulate 220 Bbls of 10.4 ppg brine while adjusting choke on IA to hold 700 psi on Tubing while taking returns to the Tiger Tank. Circulate 260 Bbls of brine while adding 67 Bbls of 12 ppg NaBr for every 250 Bbls Circulated in order to weight up to 10.7+ ppg. Shut down and monitor pressure. T/I = 30/60 psi after 30 minutes. Decide to increase EMW to 10.8-ppg; resume circulating through Pits and adding remainder of the 12-ppg NaBr to build fluid to 10.8-ppg. 09:30 - 11 :30 2.00 KILL P DECOMP S/I to monitor pressure with EMW at 10.75-ppg. Recalculate BHP with stabilized TP of 30-psi; need 11.0-ppg with 75-psi overbalance. Confer with engineer and decide to run BHP survey with Slick Line. Offload 300-Bbls of NaCI brine to Vacuum Truck. Net gain from circulating operations = - 5-Bbls. Managed to pump - 4-Bbls into the formation by holding 100-psi back pressure on the annulus during the last 100-Bbls (+/-) of circulation. 11 :30 - 12:00 0.50 KILL P DECOMP PJSM to RIU SLB Slickline equipment and discuss next steps in Well-Kill operations. 12:00 - 16:00 4.00 KILL P DECOMP P/U SLB Lubricator and BOP and bring in through Pipe Shed. RIU Sheaves and M/U Lubricator and BOP to Tree. 16:00 - 00:00 8.00 KILL P DECOMP RIH with BHP instrument, make Gradient stop, continue in to the open GLM @ 6,910' and record for 6-hours. Reservoir pressure is 3994 psi ( EMW = 11 ppg). Order and wait for spike fluid to weight system up to 11.2 ppg. 6/9/2006 00:00 - 05:30 5.50 KILL P DECOMP Order and wait for spike fluid to weight system up to 11.2 ppg. 05:30 - 10:00 4.50 KILL P DECOMP Weight up 120-Bbls of fluid in pits to 11.2-ppg brine. Pressures before circulation: Tubing 50-psi, Casing 60-psi. Circulate in at 2-BPM, start @ 310-psi Tubing, 10-psi Casing; pressures when 11.21-ppg returns to Mud Pits, Tubing 110-psi, Casing 10-psi. Total circulation 492-Bbls for 4-hours (+/-); loss to formation, 23-Bbls or 5-3/4 Bbls /hour. 10:00 - 11 :00 1.00 KILL P DECOMP SID pump and monitor well. S/I and see no pressure build-up. Open well and well is on vacuum. Monitor for 45-minutes. No flow, slight vacuum. Total fluid loss during circulation = 23-Bbls. 11 :00 - 11 :30 0.50 KILL P DECOMP P/U TWC and install in Tree. Test TWC to 3500 psi. 11 :30 - 13:00 1.50 WHSUR P DECOMP N/D Tree and Adaptor Flange. Assemble BOP stack 13:00 - 18:00 5.00 BOPSU P DECOMP Assemble BOP Stack. P/U Spacer/Adaptor Spool and install on Tubing Head. P/U BOP Stack and install on Adaptor Spool. 18:00 - 00:00 6.00 BOPSU DECOMP H/U Control Lines to BOP Stack. H/U choke and Kill lines. Modify bell nipple for 11" BOP. Install bell nipple and pressure up seals. Change upper and lower pipe rams to 2-7/8". 6/10/2006 00:00 - 03:30 3.50 BOPSU DECOMP Change pipe rams and service stack manual wing valves. Function test all components. Fill stack 03:30 - 07:30 4.00 BOPSU DECOMP Test BOPE to 250 psi and 3500 psi. Test witness waived by J. Crisp, AOGCC 07:30 - 09:30 2.00 PULL P DECOMP RIU Centrilift equipment that had been at Nabors 4ES. P/U and hang Sheave and Elephant Trunk. P/U Lopso Opso Lubricator Extension and RIH and M/U to Hanger. P/U and install Printed: 6/20/2006 12:16:15 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-24 MPC-24 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 6/5/2006 Rig Release: 6/17/2006 Rig Number: N3S Spud Date: 7/13/2001 End: 6/17/2006 6/10/2006 07:30 - 09:30 2.00 PULL P DECOMP Lubricator on Lopso Opso to pull TWC. Check annular pressure, slight vacuum. Pull TWC and see no pressure under TWC. Keep pulling TWC and hear slight vacuum when TWC is in larger diameter of Lopso Opso. 09:30 - 10:30 1.00 PULL P DECOMP RID Lubricator and Lopso Opso. P/U 2-7/8" Landing Joint, RIH and M/U to Hanger. 10:30 - 11 :00 0.50 PULL P DECOMP P/U on Landing Joint and unseat Hanger @ 57K. Stop to fill annulus and find fluid just above Hanger. Continue pulling Hanger and fluid level drops below BOP stack when Hanger gets inside stack. Turn on Mud Pit charge pump for constant hole-fill and bring fluid up into Pitcher Nipple to Flowline outlet. String comes free @ 62K, then suddenly went to 75K, but slacked off to 60-62K. Stop and monitor well and weight slacks off to 53K. Gas bubbles breaking out of fluid as fluid level slowly drops below the Pitcher Nipple and down into the BOP Stack. 11 :00 - 13:00 2.00 PULL P DECOMP Remove ESP Penetrator from Hanger. Cut ESP Cable. Hang Elephant Trunk. Attach pull-rope to ESP Cable and pull through the Elephant Trunk and M/U the Spool in Spooling Unit. 13:00 - 18:00 5.00 PULL P DECOMP POOH, SIB and strap 2-7/8", L-80, EUE, 8-Rd Tubing; spool up ESP Cable; maintain constant hole fill while POOH. At 1800-hours, 10-Bbls cummulative loss to the formation for 2-Bbls/hour fluid loss. 18:00 - 22:00 4.00 PULL P DECOMP Resume POH and SIB 2-718" tubing, strapping same. 22:00 - 23:00 1.00 PULL P DECOMP Cut off ESP cable and RD spooler, sheave and elephant trunk. 23:00 - 00:00 1.00 PULL P DECOMP Break down and layout ESP assembly. Found 8 cap screws sheared between upper and middle tandem pump sections. Seven sheared cap screw heads left in hole. Recovered 119 LeSalle clamps, 6 protectolizers and 3 flat guards. Lost 8.5 bbl 11.2 ppg brine to formation in 6 hr. TOTAL LOSS DURING TRIP 18.5 BBL. 6/11/2006 00:00 - 02:30 2.50 PULL P DECOMP Finish LD ESP pump. 02:30 - 03:00 0.50 PULL P DECOMP Clear floor and pipeshed of ESP tools and assembly. 03:00 - 06:00 3.00 PULL P DECOMP Load and strap 8-ea, 2-7/8" PAC DC and 2-7/8" PAC DP into Pipe Shed. RU to run VRT pulling tool. 06:00 - 16:00 10.00 PULL P DECOMP RIH w/ Halliburton VRT Retrieving Tool to engage and pull Halliburton Versatrieve Packer. 11 O-jts RIH @ 1130-hours. P/U #225 @ 1530-hrs, H/U TIW valve and Circulating Head. Fluid weight in Pits is 11.1 ppg at start of circulation. Fluid loss to formation while RIH wI the 2-7/8" PAC string was -1-Bbl per hour. 16:00 - 18:00 2.00 PULL P DECOMP Circulate Surface-to-Surface, -250-Bbls, 2-BPM, checking Brine weight. The fluid appeared to level out at -11.2-ppg, but decreased to 11.17-ppg. Ordered dry NaBr weighting material, discussed MW with engineer and agreed to build to 11.4-ppg. 18:00 - 20:00 2.00 PULL N FLUD DECOMP Wait on arival of dry Na Br material for weight up. 20:00 - 22:00 2.00 PULL N FWD DECOMP Mix Na Br in pits to 11.4 ppg. 22:00 - 00:00 2.00 PULL N FWD DECOMP Circulate at 3 bpm while mixing NaBr to bring entire system to 11.4 ppg. No fluid loss measured due to addition of weight material. Hole standing full. 6/12/2006 00:00 - 01 :00 1.00 PULL P DECOMP Observe well. No flow or loss. Confirm PU = 70K# & SO = 50K#. RIH and tag packer at 7207',4' in on joint #225. Wash off top of packer and work into packer bore. Slack to 7210 ft Printed: 6/20/2006 12:16:15 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-24 MPC-24 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 6/5/2006 Rig Release: 6/17/2006 Rig Number: N3S Spud Date: 7/13/2001 End: 6/17/2006 6/12/2006 00:00 - 01 :00 1.00 PULL P DECOMP with 15 K# SO. Pull to 75 K# and confirm pulling tool engaged. SO 25K# and shear Upper sleeve shifting pins. 01 :00 - 02:30 1.50 PULL N DPRB DECOMP Work PU to 100K# (30K# overpull) and observed shear. Worked SO and PU to 135K# (60K# OP). No movement. (PU limited by 75-ton, 27/8" YT elevators and by Halliburton) Work PU amd SO with no change. Evaluated results and suspected that release ring sheared before release sleeve. Decide to POH and replace shear pins in VRT tool. 02:30 - 03:00 0.50 PULL N DPRB DECOMP Work right hand torque into pipe and un-jay from packer. 03:00 - 03:30 0.50 PULL N DPRB DECOMP Flow check. Well static. RD head pin and kelly hose. 03:30 - 10:00 6.50 PULL N DPRB DECOMP POOH to re-dress packer pulling tool. 10:00 - 12:00 2.00 PULL N DPRB DECOMP Redress the Halliburton VRT tool, and insert 2 additional Shear Pins for a total of 8 x 4,700-lbs or 37,600-lbs shear. 12:00 - 17:00 5.00 PULL N DPRB DECOMP RIH w/ Halliburton VRT Tool on 2-7/8" PAC DP and DCs from Derrick. 17:00 - 18:00 1.00 PULL N DPRB DECOMP P/U and rabbit 1-joint 3-1/2" DP, install TIW valve and circulating head, stab into XO to 2-7/8" PAC DP and lower toward packer, stop and circualte 1 foot above packer at 3 bpm & 1650 psi to flush packer top. Shut down pump and confirm PU = 72K# and SO = 52 K#. 18:00 - 20:00 2.00 PULL N DPRB DECOMP Stab into packer and slack off to 42 K# (10 K stackout). PU to 85 K# and confirm latch in. SO to shear first pins. Felt light thump at 25K SO then moved down to stackout point. PU from 95K# (12 K# OP) to 115K# (32K OP) in 10K increments with 10 minutes soak between pulls. No indication of second shear or release ring movement. Pulled to 118K (35K OP) and sheared lug release pins. Work tension to 152K# (70 K# OP on J slot lugs) with no movement. Repeat process of SO to total string weight down and PU to 152K# With slow movement, rapid movement and staged movement. No change in position. 20:00 - 21 :00 1.00 PULL N DPRB DECOMP Hold 152 K tension while developing plan with engineer. 21 :00 - 22:00 1.00 PULL N DPRB DECOMP Work right hand torque to release pulling tool. Flow check. Well static. RD head pin and kelly hose. LD 3 1/2" work joint and change elevators. 22:00 - 00:00 2.00 PULL N DPRB DECOMP POOH standing back DP. 6/13/2006 00:00 - 03:00 3.00 PULL N DPRB DECOMP POOH and stand back 103 stands. Lost 2 bbl to hole while POOH. 03:00 - 04:00 1.00 PULL N DPRB DECOMP Lay down 18 singles and stand back 4 stands of drill collars. 04:00 - 05:00 1.00 PULL N DPRB DECOMP Lay down VRT pulling tool and clear floor 05:00 - 06:30 1.50 PULL N DPRB DECOMP Load Baker fishing tools to floor and MU Fishing BHA: Spear, Stop sub, Bumper sub, Jar, XO, 8 ea. Drill collar, XO, Accelerator, XO, Pump out sub. 06:30 - 11 :00 4.50 PULL N DPRB DECOMP RIH with Fishing BHA 11 :00 - 11 :30 0.50 PULL P DECOMP PUMU 3 1/2" DP single on Joint #223. RU circulating head, PU weight of 74K and SO weight of 53K. RIH and latch packer @ 7207' MD. Work jars with 25K overpull, then pulling to 150K. Trip jars 5 times and release packer. 11 :30 - 14:00 2.50 PULL P DECOMP Circulate surface to surface volume 300 bbls of 11.4 #/gal brine. No flow test well for 30 minutes. Gas bubbling and breaking out at surface, fluid level drop 4'. Gas slowing down, well stable. 14:00 - 18:00 4.00 PULL P DECOMP POH laying down 18 joints of 2 7/8" PAC DP. POH standing Printed: 6/20/2006 12:16:15 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-24 MPC-24 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 6/5/2006 Rig Release: 6/17/2006 Rig Number: N3S Spud Date: 7/13/2001 End: 6/17/2006 6/13/2006 14:00 - 18:00 4.00 PULL P DECOMP back DP in Derrick, keeping hole full by pumping across the top. Inspect strands on fast line of drilling line. Paint for awareness and to keep eye on as POH. 60 Stands OOH @ 18:00. 18:00 - 22:30 4.50 PULL P DECOMP Continue POH wI BKR Fishing BHA and HES Pkr and Screens. 22:30 - 00:00 1.50 PULL P DECOMP Stand back DC. Soft break Fishing tool BHA. Break out packer from screens and stand back packer and fishing tools in Derrick. Pull and lay down screens and tail pipe. There was no indication of external damage or pack off on the packer, screens or tail pipe. All surfaces were clean. One packer seal element was missing, one was half gone and one was intact. All slip dies were intact, sharp and free floating. There was no appearant malfunction of the packer. The packer will be shopped for inspection and re-dressing. The screens were clean inside and had no external packoff in the holes. The Tailpipe was completely filled with very fine grained white material, probably Carbolite. 6/14/2006 00:00 - 01:00 1.00 PULL P DECOMP Flow check well. Close blind rams and set packer in rotary table. Release spear and lay down packer. Open blind rams. Lay down fishing tools. 01 :00 - 02:30 1.50 CLEAN P CLEAN Clear floor of fishing handling tools. Load 2 3/8" handling tools from pipe shed. 02:30 - 06:00 3.50 CLEAN P CLEAN M/U mule shoe wash tool. RIH w/40 singles of 2 3/8" RTS6 DP from pipe shed. Continue in hole wI 4 stands of 2 7/8" PAC Drill Collars and 2 718" PAC drill pipe. 06:00 - 09:30 3.50 CLEAN P CLEAN RIH wI FCO BHA on 2 7/8" PAC DP to 7396', get PU wt of 70 K#'s and SO wt of 50 K#'s 09:30 - 13:00 3.50 CLEAN P CLEAN PU singles of 2 7/8" PAC DP and tag fill @ 8122'. PU wt of 80 K#'s, SO wt of 55 K#'s. Hole out of balance. RU circulating head, PU to 8100' and reverse circulate 1.5 times tbg volulme. RIH and attempt to reverse out from 8122'. DP plugging, PU and RIH jetting to 8145'. Reverse at 3 BPM /1800 psi bottoms up and recover big chunk of packer rubber. Pump viscous sweeps every 100 bbls down annulus as reverse circulating FCO 13:00 - 16:00 3.00 CLEAN P CLEAN Reverse FCO @ 3 BPM I 950 psi thru perf intervals at 8162'-8172' and 8191'-8201'. Losses to formation of 1.25 BPM as reversing @ 3 BPM I 950 psi. 16:00 - 17:00 1.00 CLEAN P CLEAN Mix new 30 Bbls of Duo-Vis pill for final sweep and pump down annulus as FCO from 8250'. 3 BPM I 850 psi, losses of 1.25 BPM 17:00 - 19:00 2.00 CLEAN P CLEAN FCO to 8311' MD. Reverse circulate until final 30 Bbl viscous sweep returned. Continue reversing at 3 bpm & 1400 psi to balance MW. Total loss of 182 Bbl since starting to circulate. Aproximately 5 Bbl Carbolite recovered off shakers. 19:00 - 19:30 0.50 CLEAN P CLEAN Flow check well. Had slight flow back on casing and DP sides. 19:30 - 20:00 0.50 CLEAN P CLEAN Reverse circ BU to confirm well MW balance at 11.4 ppg. Lost 7 bbl to formation. 20:00 - 20:30 0.50 CLEAN P CLEAN Flow check. Stronger flowback on DP than previous check. 20:30 - 22:15 1.75 CLEAN P CLEAN Circulate surface to surface down DP taking returns through choke at 3 BPM /1400 psi. FCP = 1440 psi @ 3 bpm. Printed: 6120/2006 12:16:15 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-24 MPC-24 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 6/5/2006 Rig Release: 6/17/2006 Rig Number: N3S Spud Date: 7/13/2001 End: 6/17/2006 6/14/2006 22:15 - 22:45 0.50 CLEAN P CLEAN Flowcheck well. Fluid dropping in both annulus and drill pipe at 2.5 bbl/hr. Lay down circulating head and TIW valve. 22:45 - 23:45 1.00 CLEAN N RREP CLEAN Attempt to lay down 2 7/8" DP. Pipe skate non functional. Replace damaged proximity switch and test skate. 23:45 - 00:00 0.25 CLEAN P CLEAN POOH laying down 2 7/8" DP. Cumulative fluid loss for 24 hours = 192.7 bbl. 6/15/2006 00:00 - 06:00 6.00 CLEAN P CLEAN POH laying down 2 7/8" drill pipe. Lost 34 bbl brine to reservoir in 6 hr. 06:00 - 10:30 4.50 CLEAN P CLEAN Crew change. Continue POH laying down 2 7/8" DP and 2 3/8" DP. Losses @ - 6 Bbl/hr. 140 Bbls of 11.4 #/gal brine in pits. 10:30 - 13:30 OTHCMP C & C rig floor. PJSM wI SLB TCP. PUMU 253' BHA - 2 7/8" 6 SPF 2906PJ Omega. OAL=338.5'. RA sub to top shot=107.82'. Loaded to perf intervals from 7987'-7995' (8ft), 8162'-8172' (10ft), 8191 '-8216" (25 ft). 13:30 - 18:30 OTHCMP RIH wI TCP BHA on 2 3/8" DP and 2 7/8" Tbg. PU wt of 55 K#'s and SO wt of 40 K#'s. Set tbg and guns wI 2' of Tbg stickup through rotary table. MU XO to 3 1/2" IF wI TIW valve. 235 Bbls of 11.4 #/gal brine in pits. Losses @ -6 Bbl/hr. 18:30 - 20:30 OTHCMP PUMU SLB e-line stripper head, pump in sub, and equipment to rig floor.PJSM for E-Line run. RU e-Line sheavs and stripper head. RIH wI GRlCCL and zero depth. RIH to 7930' WLM. 20:30 - 22:15 OTHCMP Log up to 7650' for corelation. Found apparant 27' discrepancy between WLM and pipe tally. Drop to 7930' and log up to 6990' to confirm work string configuration by CCL and GR correlation to Sperry MWD log of 7/25/01. Concluded that there was a 26.18' discrepancy between W LM and workstring tally. 22:15 - 23:15 OTHCMP CCL log OOH wI CCL at normal pulling speed. Confirm work string joint count. Source of discrepancy remains undetermined. 23:15 - 00:00 OTHCMP RID E-LIine. P/U 1 joint 2 7/8" tubing and RIH 26.18'. RlU E-Line. Fluid loss stable at 3.2 bph. Total loss past 24 hours = 43bbl. 6/16/2006 00:00 - 01 :45 1.75 P OTHCMP M/U E-Line wiper and Pump in sub. RIH to 7920'. 01 :45 - 02:30 0.75 P OTHCMP Log up to 7110' to confirm work string configuration by CCL and GR correlation to Sperry MWD log of 7/25/01. Confirm GR corelation and locate PIP collar at 7879'. 02:30 - 03:45 1.25 OTHCMP POOH and rig down E-Line. 03:45 - 05:00 1.25 OTHCMP RU circulating head. Drop shifting ball and MU circulating hose. Close annular and take returns through choke. Fill hole with 4.76 bb and seat ball with .25 additional bbl. Pressure to 2460 psi with 0.66 bbl and fired guns. Closed choke and monitored for pressure. None observed. Open annular and POH 4 stands with 55K# . No excess drag. Perforated intervals 7987' to 7995',8162' to 8171', and 8191' to 8216' with 6 spf. 05:00 - 05:15 0.25 PERFO OTHCMP Flow check. Lost 0.75 bbl in 15 min. = 3 bph. 05:15 - 12:00 6.75 PERFO OTHCMP POH with TCP assembly. Strap 2 7/8" Tbg in Derrick. 12:00 - 17:30 5.50 PERFO OTHCMP BOLD 2 3/8" DP and SLB perforating equipment. Losses-4 Bbl/hr. Total losses to formation during POH of 23 Bbls. 17:30 - 19:30 2.00 RUNCMP Clear floor and pipe shed of perforating work string handling tools. Load completion equipment into pipe shed and prep for running ESP completion. 19:30 - 23:00 RUNCMP PUMU ESP. Connect cable and test continuity. Install flat Printed: 6/20/2006 12:16:15 PM , .. e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-24 MPC-24 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 6/5/2006 Rig Release: 6/17/2006 Rig Number: N3S Spud Date: 7/13/2001 End: 6/17/2006 cable protectors. RIH with XN Nipple and first stand. Installing round cable clamps every collar. Lost 85 bbl to formation in past 24 hr. RIH with ESP completion to 743'. ESP spooler cable birdsnested when operator over-ran block running speed. Untangle ESP cable birds nest and re-tension on spool. RIH slow while working birds nest out of ESP cable. RIH at normal speed. 65 of 108 stands in the hole. Losses @ -2 Bbls/Hr. RIH wI ESP on 219 joints of 2 7/8" 6.5 #/ft EUE 8 Rd Tbg, 10 ea 2 7/8" 6.5 #/ft pup joints, XN nipple wI XXN plug, 3 GLM's wI bottom station open and DGL V's in top two. PUMU FMC 11" x 2 7/8" hanger wI penetrator and TWC installed. PU wt of 57K #'s and SO wt of 42K #'s RUNCMP Centrilift cut and make connection for attaching cable to penetrator. RUNCMP Final checks on ESP. Sensor @ 6121' TVD, 147 deg F, 3606 psi. Phase to Phase - 3.0 balanced I Phase to Ground of 780 M. Land completion and RILDS. Test TWC to 2500 psi. Lay down landing joint, ESP shieve, clean and clear rig floor. Total losses of 424 Bbls 11.4 #/gal brine to formation during workover. Rig down choke and kill lines. Rig down BOP control lines. Nipple down bell nipple and flow line Split BOP and set out Annular, double gate ram body and single gate ram body with adapter flange and mud cross. PU tree and land over ESP Penetrator. MU to tubing head. Test tree adapter seals to 5000 psi. Test ESP conector continuity. Centrilift noted miss-oriented penetrator. The alignment lug on the recepticle was rotated 75 degrees counter clockwise from the optimal position. Penetrator could not be repositioned without unlanding tubing. Contacted pad operator and made trial connection of ESP umbilical. Compared alignment to other ESP completion on the pad. Confirmed that umbilical connection was functional and alignment was acceptable. Re-stowed umbilical. Tested tree to 5000 psi. WHDTRE RU lubricator. Pulled TWC. Slight vacuum on tubing. Set BPV and RD lubricator. Released rig at midnight June 17, 2006. 6/17/2006 00:00 - 01 :45 1.75 RUNCMP 01 :45 - 02:30 0.75 SFAL RUNCMP 02:30 - 03:00 0.50 RUNCMP 03:00 - 06:00 3.00 RUNCMP 06:00 - 10:00 4.00 RUNCMP 10:00 - 12:00 2.00 12:00 - 14:00 2.00 14:00 - 18:00 4.00 BOPSU P RUNCMP 18:00 - 20:00 2.00 BOPSU P RUNCMP 20:00 - 22:00 2.00 WHSUR P WHDTRE 22:00 - 23:30 1.50 WHSUR P WHDTRE 23:30 - 00:00 0.50 WHSUR P Printed: 6/20/2006 12:16:15 PM e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_ Inserts\Microfilm _ Marker. doc Permit to Drill 2010940 DATA SUBMITTAL COMPLIANCE REPORT 8~25~2003 Well Name/No. MILNE PT UNIT KR C-24 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-23020-00-00 MD 8406 / -I-VD 7228 / Completion Dat 8/23/2001 / Completion Statu 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N__g_o Sample N_.9o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH / Dataset Name Scale Media No Start Stop CH Received Number Comments Directional Survey FINAL OH 9/7/2001 Directional Survey ~ C Ver LIS Verification i~ c D Ver LIS Verification GYRO Directional Survey Directional Survey MWD ~Dynamics Tester Directional Survey GYRO Directional Survey Directional Survey MWD 1 112 8344 Open 5/9/2002 '110806 FINAL 7250 8295 ch 10/16/2001 ~1,0376 7250-8295 Digital Data FINAL OH 9/7/2001 Directional Survey FINAL OH 9/7/2001 Directional Survey I 112 8344 Open 3/4/2002 ~1'b640 FINAL 7805 8259 CH 8/3/2001 7805-8259 BL, Sepia FINAL OH 9/7/2001 Directional Survey DIGITAL DATA FINAL OH 9/7/2001 Directional Survey DIGITAL DATA FINAL OH 9/7/2001 Directional Survey DIGITAL DATA Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/~...~ Chips Received? '-¥-f-N-~' Analysis R ~.c~.iv~.d ? Daily History Received? ~)/N Formation Tops ~,~ N Permit to Drill 2010940 MD 8406 TVD DATA SUBMITTAL COMPLIANCE REPORT 8~25~2OO3 Well Name/No. MILNE PT UNIT KR C-24 Operator BP EXPLORATION (ALASKA) INC 7228 Completion Dat 8/23/2001 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-23020-00-00 UIC N Comments: Compliance Reviewed By: Date: To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Cornrn. Attn.' Lisa Weepie 333 West 7~ Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPC-24, AK-MM-11117 March 8, 2002 MPC-24: Digital Log Images: 50-029-23020-00 1 CD Rom PLEASE ACKNOWLEDGE iRECEIPT BY SIGNING AND iRET'U'RNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 .E. iBenson iBl.v'd. Anchorage, Alaska 99508 Date: WELL LOG TRANSMITTAL To: State of Alaska February 26, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPC-24, AK-MM-11117 1 LIS formatted Disc with verification listing. API#: 50-029-23020-00 ~ ©t-oq q PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services .Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99648 BP iExploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: RECEIVED I"'~o 0 ~. 2002 l:-~,~, ~ . Alaska Oil & Gas Cons. Commissio~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Acidize ESP/Screens Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface 4108' FNL, 2446' FEL, Sec. 10, T13N, R10E, UM At top of productive interval 1281' FNL, 17' FEL, Sec. 15, T13N, R10E, UM At effective depth 1341' FNL, 3' FEL, Sec. 15, T13N, R10E, UM At total depth 1381' FNL, 5274' FEL, Sec. 14, T13N, R10E, UM 5. Type of Well: Development __X Explorato~._ Stratigraphic._ Service_ (asp's 558013, 6029452) (asp's 560466, 6027018) (asp's 560480, 6026958) (asp's 560489, 6026919) 6. Datum elevation (DF or KB feet) RKB 45 feet 7. Unit or Property name Milne Point Unit 8. Well number MPC-24 9. Permit nu,,m..be[/__approval number ....,~,~.~ ~..,.! !.~'~. ~' :~,:? ~. ~'",'."'i~' ~ "' ~: " , · ,~.~::.~...~~-"., _. 10. APl number 50-029-23020-00 11. Field/Pool Milne Point Unit/Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 82' Surface 5027' Production 7651' Liner 912' 8406 feet Plugs (measured) 7228 feet 8298 feet Junk (measured) 7127 feet Size Cemented Measured Depth True Vertical Depth 20" 260 sx Arcticset (Approx) 113' 113' 9-5/8" 714 sx PF 'C', 360 sx 5057' 2432' Class 'G' 7" 170 sx Class 'G' 7679' 6580' 4-1/2" 115 sx Class 'G' 7494' - 8406' 6424' - 7228' Perforation depth: Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) measured Open Perfs 8162'- 8172', 8191'-8201' J~ECE/VED true vertical Open Perfs 7003'- 7012', 7029'- 7038' ~J, ~"'~'~ .~ ~- ~4~ 2-7/8", 6.5#, L-80 to 7097'; 2-7/8". 6.5#, L-80 from 7396' to 7428. /l~'""0~' ESP pump from 7097' to 7170'. ~8$~O/l&'""'ura~,, CO~i~Sio~ 7" HES Versa-trieve PKR @ 7206'; 7" x 4-1/2" Baker 'S-3' PKR @ 7402'. 7" x 4-1/2" Baker 'ZXP' PKR @ 7494'; Camco 2-7/8" x 1" sidepocket KBMM GLM @ 187'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 01/01/2002 Subsequent to operation 01/07/2002 Representative Daily Average Production orlniection Data Oil-Bbl Gas-Mcr Water-Bbl 691 255 103 773 273 13 Casing Pressure Tubing Pressure 333 342 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil _X Gas _ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~~~,t./-~~~~ Title: Technical Assistant DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · Date January 29 2~002 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLIC^T~~ MPC-24 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 12/07/2001 PUMPING: FREEZE PROTECT DUE TO FIELD SHUT DOWN. 01/03/2002 PUMP OPERATION: SI TREATMENT ACID JOB. EVENT SUMMARY 12/07/01 WELL WOULD NOT SURFACE FLUID. PUMPED 5 BBLS OF METHANOL DOWN TUBING AT 0.6 BPM/225 PSI. MAY HAVE HAD A SLIGHT INDICATION OF HYDRATES. PUMPED 7 BBLS OF METHANOL DOWN FLOWLINE. STARTED ESP UP AND RUNNING FINE NOW. 01/03/02 PERFORMED SCALE INHIBITOR USING 9 BBLS OF NALCO EC 6097A. OVER FLUSHED SI CHEMICALS BY 100 BBLS AND LET SOAK FOR 6 HOURS. RIG BACK UP AND PUMP 15 BBLS OF 10% DAD ACID ACROSS THE ESP AND DOWNHOLE SCREENS. LET ACID SOAK FOR 30 MINUTES. THEN GARGLED AND SPIT THE ACID AT 35 HZ TO A TANK UNTIL PH WAS NEUTRAL. SAW SOME SMALL BREAK WHILE LOADING THE INNER ANNULUS WITH DEAD CRUDE. FLUIDS PUMPED BBLS 14 METHANOL 38 SOURCE WATER 230 CRUDE 15 10% DAD ACID 9 EC6097A ACID 3O6 TOTAL Page 1 bp .,. .\1'.'". -.......~ ~....- ~...- ~..~ ~.~ F"'-' .'I'~~I\' ". Terrie Hubble Direct: (907) 564-4628 hubbletl@bp.com Technical Assistant GPB Drilling & Wells BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 November 2, 2001 Alaska Oil & Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 Reference: 10-404, MPC-24 Attached, please find a revised 10-404 for the latest workover on MPC-24, Permit Number 201- 094, API Number 50-029-23020-00. We recently discovered that a string of 3-1/2" Poroplus Screens was erroneously omitted from the previously submitted report. The previously submitted attachments are correct and need to be retained. Please discard only the 10-404 that was signed and dated on 10-03-01 and put this revised one in its place. I apologize for any inconvenience that this may cause, but felt that it was important to correct the OtnlSSlon. Sincerely, ~~ Terrie Hubble RECEIVED NOV 0 5 2001 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS REVISED: 11/01/01 1. Operations performed: 0 Operation Shutdown 0 Stimulate B Pull Tubing 0 Alter Casing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 0 Plugging 0 Perforate B Repair Well BOther 5. Type of well: IBI Development 0 Exploratory 0 Stratigraphic 0 Service Change Out ESP 6. Datum Elevation (DF or KB) KBE = 44.80' 7. Unit or Property Name Milne Point Unit 4. Location of well at surface 1171' NSL, 2446' WEL, SEC. 10, T13N, R10E, UM At top of productive interval 3998' NSL, 17' WEL, SEC. 15, T13N, R10E, UM At effective depth 3937' NSL, 3' WEL, SEC. 15, T13N, R10E, UM At total depth 3898' NSL, 5274' WEL, SEC. 14, T13N, R10E, UM 12. Present well condition summary Total depth: measured true vertical 8. Well Number MPC-24 9. Permit Number / Approval No. 201-094 10. API Number 50- 029-23020-00 11. Field and Pool Milne Point Unit / Kuparuk River Sands Effective depth: measured true vertical 8406 feet 7228 feet 8298 feet 7127 feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 82' 20" 5027' 9-5/8" 7651' 7" 912' 4-1/2" 260 sx Arctic Set (Approx.) 714 sx PF 'C', 360 sx Class 'G' 113' 5057' 113' 4609' 170 sx Class 'G' 115 sx Class 'G' 7679' 7494' - 8406' 6580' 6424' - 7228' Perforation depth: measured A3 Sands - 8162' - 8172'; A2 Sands - 8191' - 8201' true vertical A3 Sands - 7003' - 7012'; A2 Sands - 7029' - 7038' Tubing (size, grade, and measured depth) 2-7/8",6.5#, L-80 to 7175'; 3-1/2" Screen Assembly from 7206' to 7335'; 4-1/2", 12.6#, L-80 from 7396' to 7428' Packers and SSSV (type and measured depth) 7" HES Versa-trieve packer at 7206'; 4-1/2" Baker 'S-3' packer at 7402' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure NOV 0 5 2001 Alaska Oil & Gas Cons. Commission 14. Reoresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 0 Copies of Logs and Surveys run 0 Daily Report of Well Operations 17. I hereby certify that the for going is true and correct to the best of my knowledge 16. Status of well classifications as: IBI Oil 0 Gas 0 Suspended Service Si ned Terrie Hubble Title Technical Assistant Date [ .O~.OI Form 10-404 Rev. 06/15/88 ORtG1NAL Prepared By Name/Number: Terrie Hubble, 564-4628 Submit In Duplicate BP EXPLORATION Page I of 2 Operations Summa Report Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: RE ENTER Start: 10/1/2001 End: Contractor Name: NABORS Rig Release: 8/23/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase i Description of Operations 10/1/2001 00:00- 01:00 1.00 MOB P DECOMP RAISEAND SCOPE DERRICK. ACCEPTED RIGAT01:00 HRS. 01:00-02:30 1.50 MOB P DECOMP RU TIGER TANK AND TAKE ON 10 LB/GAL BRINE IN RIG PITS. 02:30 - 04:00 1.50 MOB P DECOMP RU HCR VALVE AND LINES TO ANNULUS. 04:00 - 05:00 1.00 MOB P DECOMP RIG UP LUBRICATOR AND PULL BPV. 05:00 - 06:00 1.00 MOB P DECOMP FINISH RIGGING UP LINES TO TREE. TEST LINES TO 3,500 PSI. 06:00 - 09:00 3.00' KILL P DECOMP HOLD PRE-JOB SAFETY AND OPERATION MEETING. KILL WELL WI10# BRINE DOWN TBG...TAKING RETURNS TO TIGER TANK. 09:00 - 09:30 0.50 KILL P DECOMP MONITOR WELL. RD HARDLINES. 09:30- 10:00 0.50 REST P DECOMP SETAND PRESSURE TESTTWC. 10:00 - 11:00 1.00 REST P DECOMP REMOVE X-MASS TREE. 11:00 - 13:00 2.00 REST P DECOMP N/U BOPs. 13:00 - 16:30 3.50 REST P DECOMP TESTED BOPs, KELLY AND SHOCK HOSE TO 250 PSI LOW AND 3,500 PSI HIGH. 16:30 - 17:30 1.00 REST P DECOMP P/U LUBRICATOR, PULLED TWC AND LAID DOWN SAME. 17:30 - 18:30 1.00 REST P DECOMP M/U LANDKING JOINT, PULLED HANGER WITH 65,000 LBS. LAID DOWN HANGER AND LANDING JOINT. 18:30 - 00:00 5.50 REST P DECOMP POH WITH 2 7/8 TGB AND SPOOLED CABLE ON SPOOL. 10/2/2001 00:00 - 03:00 3.00 REST P DECOMP LAID DOWN ESP PUMP AND INSPECTED SAME. PUMP WAS NOT PACKED WITH SAND. 03:00 - 05:00 2.00 REST P DECOMP INSPECTED AND LAID DOWN SCREENS. SCREENS WERE NOT PLUGGED WITH SAND. RECOVERED 4 GALLONS OF SAND AFTER REMOVING BULL PLUG AT BOTTOM OF SCREENS. 05:00 - 06:00 1.00 REST P DECOMP CLEARED AND CLEANED RIG FLOOR. 06:00 - 08:00 2.00 REST P DECOMP RIGGED UP HOWCO SLICK LINE. 08:00 - 10:30 2.50 REST P DECOMP RIH WITH 6" GAUGE RING / JUNK BASKET. STOPPED AT 7270' SLM. 10:30 - 11:30 1.00 REST P DECOMP RUN #2. RIH WITH 1.75" BAILER AND TAGGED CARBOLITE AT 7968'. HAD CARBOLITE IN SAMPLE CATCHER. 11:30 - 12:30 1.00 REST P DECOMP RIGGED DOWN W/L LUBRICATOR. 12:30 - 14:00 1.50 REST P DECOMP P/U KELLEY. CHANGED OUT UPPER KELLY VALVE. TESTED TO 3,500 PSI. 14:00 - 15:30 1.50 REST P DECOMP RIH WITH 2 3/8 MULE SHOE AND 30 JOINTS OF 2 3/8 PH 6 TBG. 15:30 - 19:00 3.50 REST P DECOMP RIH WITH 2 7/8 TBG TO 7891'. 19:00 - 19:30 0.50 REST P DECOMP ATTEMPTED TO INJECT IN FORMATION. PRESSURED TO 2,500 AND DID NOT PUMP IN FORMATION. 19:30 - 21:00 1.50 REST P DECOMP POH TO TOP OF PACKER AT 7321'. REVERSED CIRCULATED ANNULAR VOLUME. 21:00 - 00:00 3.00 REST P DECOMP RIH. TAGGED SAND AT 7961. BEGAN CLEAN OUT BY REVERSE CIRCULATING. CLEANED OUT TO 8017 AT MIDNIGHT. 10/3/2001 00:00 - 05:00 5.00 REST P DECOMP CONTINUED TO REVERSE CIRCULATE AND WASH TO 8300'. 05:00 - 06:00 1.00 REST P DECOMP STAND PIPE PARTIALLY PLUGGED WITH DEBRIS. STOPPED PUMPING. MONITORED WELL. WELL FLOWING. SHUT IN. HAD 120 PSI ON ANNULUS. 06:00 - 07:00 1.00 REST P DECOMP CONTINUED TO REVERSE CIRCULATE AND WORKED DEBRIS FREE. Printed: 10/8/2001 1:15:32 PM BP EXPLORATION Page 2 of 2 Operations Summa Report Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: RE ENTER Start: 10/1/2001 End: Contractor Name: NABORS Rig Release: 8/23/2001 Rig Name: N^BORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 10/3/2001 07:00 - 08:00 1.00 REST P DECOMP POH 5 STANDS TO 7825'. PERFORMED INJECTION TEST. PUMPED 20 BBLS AT 2 BPM AT 900 PSI. 08:00 - 10:00 2.00 REST P DECOMP RIH. DRY TAGGED AT 8271. POH TO 8050. 10:00 - 14:00 4.00 REST P DECOMP SHUT IN WELL. CLEANED PITS AND WAIT ON 10.0 PPG BRINE. 14:00 - 19:00 5.00 REST P DECOMP TAKE ON BRINE AND WEIGHT UP TO 10.4 PPG. 19:00-21:00 2.00 REST P DECOMP KILLED WELL WITH 10.4 PPG BRINE. PUMPED CONTAMINATED 10.0 BRINE FROM HOLE TO TIGER TANK. PUMPED 3 BPM. 21:00 - 22:30 1.50 REST P DECOMP AFTER PUMPING CALCULATED SURFACE TO SURFACE STROKES, SHUT IN AND MONITORED PRESSURE. CONTINUED PUMPING AND TAKING RETURNS TO PITS. WITH 10.4 PPG IN AND OUT, SHUT DOWN AND MONITORED WELL. WELL DEAD. 22:30 - 00:00 1.50 REST P DECOMP POH WITH 2 7/8 TBG. 10/4/2001 00:00 - 02:30 2.50 REST P DECOMP POH WITH 2 7/8 TBG AND SLM. 02:30 - 03:30 1.00 REST P DECOMP LAID DOWN 2 3/8 TBG. 03:30 - 04:00 0.50 REST P DECOMP PJSM FOR RUNNING VTL PACKER AND SCREEN ASSY. 04:00 - 04:30 0.50 REST P DECOMP RIGGED UP TO RUN SCREENS AND PACKER. 04:30 - 12:00 7.50 REST P DECOMP RUN SCREEN ASSY AND VTL PACKER. RIH WITH 2 7/8 TBG. TAGGED 4 1/2' TBG STUB AT 7392'. PULL UP 60'. 12:00 - 13:00 1.00 REST P DECOMP DROPPED BALL AND SET VTL PACKER AT 7202'. TESTED PACKER TO 2,500 PSI. 13:00 - 16:00 3.00 REST P DECOMP POH WITH 2 7/8 TBG. LAID DOWN 14 JOINTS. STOOD BACK 71 STANDS IN DERRICK. 16:00 - 16:30 0.50 REST P DECOMP CLEANED RIG FLOOR AND RIGGED UP TO RUN 2 7/8 ESP COMPLETION. 16:30 - 22:30 6.00 REST P DECOMP P/U AND SERVICED ESP. 22:30 - 00:00 1.50 REST P DECOMP RIH WITH 2 7/8 AND ESP COMPLETION. 10/5/2001 00:00 - 04:30 4.50 REST P DECOMP FINISH RIH W/ESP ASSY AND 2 7/8" TBG. 04:30 - 05:00 0.50 REST P DECOMP MAKE UP LANDING JT AND HANGER. 05:00 - 06:30 1.50 REST P DECOMP MADE EFT CONNECTOR SPLICE. ATTACHED AND SECURED ESP CABLE AND TESTED SAME. 06:30 - 07:00 0.50 REST P DECOMP LANDED HANGER. STRING WEIGHT 62K UP AND 45K DOWN. RILDS. 07:00- 07:30 0.50 REST P DECOMP SET TWC AND TESTED SAME. DRAINED BOPs. R/D LINES. 07:30- 09:00 1.50 REST P DECOMP N/D BOPs. 09:00 - 10:00 1.00 REST P DECOMP N/U TREE. 10:00 - 10:30 0.50 REST P DECOMP TESTED ADAPTOR FLANGE AND TREE TO 5,000 PSI. TESTED ESP. 10:30 - 12:00 1.50 REST P DECOMP P/U LUBRICATOR. PULLED TWC. SET BPV. 12:00- 14:30 2.50 REST P DECOMP FREEZE PROTECTED TUBING AND ANNULUS. PUMPED 75 BBLS OF DIESEL IN ANNULUS AND 15 BBLS IN TUBING. 14:30 - 15:00 0.50 REST P DECOMP BLEW DOWN HARD LINES AND SECURED TREE. RELEASED RIG AT 15:00 HRS ON 10-05-01. RDMO. MOVED RIG TO F-78. Printed: 10/8/2001 1:15:32 PM 10/05/01 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 15'10 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD L2-'18A ~C~_/0 ~. LEAK DETECTION LOG 09/17/01 1 1 MPC-24 c~) '"(-~ Hq 21385 PERF RECORD GR (PDC) 08/02/01 D.S. 11-01A /c~ o~ - II ~, 21392 'RST-SIGMA 06/09198 P1-02 I ~"-O~)~_,% 2123'1 RST-SlGMA 04/2'1/01 '1 '1 B'05~ /~ ~.~ -2'1332 MCNL 06/29/01 1 '1 '1 D.S. 1t-01A ~c~c:~ - ~tc:~. 21232 RST-SIGMA 04/28/01 1 '1 M-24A c~O/-/~ (~ 21360 MCNL 08104101 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED OCT 1 6 2001 Alaska Oil & Gas Cons. Commissio~ Anchorage Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Received by~ ~ o, ^,^s,^ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 44.80' 3. Address [] Exploratory 7. Unit or Property Name [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1171' NSL, 2446' WEL, SEC. 10, T13N, R10E, UM MPC-24 At top of productive interval 9. Permit Number / Approval No. 201-094 3998' NSL, 17' WEL, SEC. 15, T13N, R10E, UM 10. APl Number At effective depth 50-029-23020-00 3937' NSL, 3' WEL, SEC. 15, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 3898' NSL, 5274' WEL, SEC. 14, T13N, R10E, UM Sands 112. Present well condition summary Total depth: measured 8406 feet Plugs (measured) true vertical 7228 feet Effective depth: measured 8298 feet Junk (measured) true vertical 7127 feet Casing Length Size Cemented M D TVD Structural Conductor 82' 20" 260 sx Arctic Set (Approx.) 113' 113' Surface 5027' 9-5/8" 714 sx PF 'C', 360 sx Class 'G' 5057' 4609' Intermediate Production 7651' 7" 170 sx Class 'G' 7679' 6580' Liner 912' 4-1/2" 115 sx Class 'G' 7494' - 8406' 6424' - 7228' Perforation depth: measured A3 Sands - 8162' - 8172'; A2 Sands - 8191'- 8201' true vertical A3 Sands - 7003' - 7012'; A2 Sands - 7029' - 7038' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 7268' and 2-7/8", 6.5#, L-80 from 7396' to 7428'. Packers and SSSV (type and measured depth) 4-1/2" S-3 Baker Model packer at 7402' MD. RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) OCT 0 4 Z001 Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. Commission Anchorage i4. Representative Daily Average Production or Injection Data ' OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: ~ 5. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and cqrrect to the best of my knowledge _..~ ' __ Signed Sond .... ___Title Technical Assistant Date tO "(~5 '~) / Prepared By Name/Number: Sondra Stewman, 564-4750 ' Form 10-404 Rev. 06/15/88 ORIGINAL Submit In Duplicate BP EXPLORATION Page I of 1 Operations Summa Report Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 ;Event Name: RE ENTER Start: 9/12/2001 End: Contractor Name: NABORS Rig Release: 8/23/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 9/12/2001 04:00 - 08:00 4.00 MOB P DECOMP RIG MOVE FROM MPL-29 TO MPC-24. DERRICK LAGGING BEHIND(SLIGHT MOD TO PONY WlNDWALL). 08:00 - 12:00 4.00 RIGU P DECOMP MIRU NABORS 4ES ON C-24. BERM & SET RIG MATS- SPOT RIG. RAISE AND SCOPE DERRICK. 12:00-15:00 3.00 KILL P DECOMP ACCEPT RIG. BERM TIGERTANK. RUN HARDLINE. RU HARDLINE TO TO TREE-HCR VALVE TO ANNULUS. PU LUBRICATOR & PULL BPV 15:00 - 16:00 1.00 KILL P DECOMP TAKE ON 9.4 BRINE. PT HARDLINES TO 3500 PSIG. 16:00 - 16:30 0.50 KILL ip DECOMP WELL BRIEFING W/TP, RIG CREW, AND BAROID MUD MAN. CALL MILNE PT FOR GAS VENTING OPS. 16:30 - 20:00 3.50 KILL P DECOMP OPEN UP TO WELL: TUBING P= 590 PSlG, ANN P= 610 PSIG. START CIRCULATION KILL W/9.4 BRINE. 20:00 - 21:30 1.50 KILL P DECOMP MONITOR WELL. SMALL AMT OF GAS COMING OF ANNULUS. LET BREATH. 21:30 - 22:30 1.00 WHSUR P DECOMP SET TVVC. ND TREE. 22:30 - 00:00 1.50 BOPSUF P DECOMP PJSM. NIPPLE UP BOPE STACK. 9/13/2001 00:00 - 03:00 3.00 BOPSUR P DECOMP WEEKLY BOPE TEST. (AOGCC REP. JEFF JONES WAIVED RIGHT TO WITNESS). 03:00 - 03:30 0.50 BOPSUR P DECOMP PU LUBRICATOR AND PULL TWC. 03:30 - 04:00 0.50 PULL P DECOMP MU LANDING JT IN HANGER. BOLDS. PULL HANGER TO RIG FLOOR. PU WT= 62K. 04:00 - 06:00 2.00 PULL P DECOMP CHECK'ESP CABLE. BACK OFF HANGER. TIE BACK CABLE TO SPOOLER. 06:00 - 12:00 6.00 PULL P DECOMP TOH W/ESP COMPLETION. 12:00 - 14:30 2.50 PULL P DECOMP INSPECT PUMP. LD PUMP & PHOENIX MS. 14:30 - 15:00 0.50 PULL P DECOMP CLEAR AND CLEAN RIG FLOOR. PREP TO RUN 2-3/8' PH-6. 15:00 - 20:00 5.00 CLEAN P DECOMP TIH W/36 JTS OF 2-3/8" PH-6 TBG(1149'). XO TO 2-7/8" TBG. TIH W/2-7/8". TAG DOWN ON PKR. WORK AND MAKE IT THROUGH. TBG STARTED SLIGHT FLOW (SAND BRIDGE?). 20:00- 23:00 3.00 CLEAN P DECOMP REVERSE CIRC BTMS UP. HAVE 8.8 PPG RETURNS. CONTINUE REV CIRC UNTIL RETURNS 9.4 PPG. TBG STILL HAS SLIGHT FLOW. ClRC OUT GAS BUBBLE THE LONG WAY. WELL OK. 23:00 - 00:00 1.00 CLEAN P DECOMP CONT. TIH W/2-7/8 TBG. TAG FILL @ 7640'. PREP TO REV CIRC. Printed: 9/17/2001 4:26:05PM STATE OF ALASKA !" ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service [] TSUSP 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-094 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ~ 50- 029-23020-00 4. Location of well at surface ~ r.....: ..:. ':.'-";~-,-.-~ j '-,.~__~_,,,'-,,. 9. Unit or Lease Name i i ,,~'. u.. ' ~,,.~;,, ~ 1171 NSL, 2446' WEL, SEC. 10, T13N, R10E, UM ~ ~:'..'i'~ '!~~i Milne Point Unit At top of productive interval i _~:_23. :._~L ! 3998' NSL, 17' WEL, SEC. 15, T13N, R10E, UM .~ .... . ....... ;; ' At total depth I ~-~' i ' 10. Well Number 3898' NSL, 5274' WEL, SEC. 14, T13N, R10E, UM !~¥: ...... c-;::~¥;.~ MPC-24 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation ani~l~erial No. 11. Field and Pool Milne Point Unit / Kuparuk River Sands KBE = 44.80' ADL047437 12. Date Spudded7.13.2001 113' Date T'D' Reached 114' Date C°mp" Susp"-~°r Aband> JS~ Water depth' if °fish°re 116' N°' °f C°mpleti°ns7-25.2001 8~3/-200~ ,¢'//~.~ / - N/A MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1'20. Depth where SSSV set121. Thickness of Permafrost 8406 7228 FTI 8298 7127 FTI . [] Yes [] NoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run Dir, GR, Gyro, ABGR, Res, PWD, Neutron, Dens, CCL 23. " . CASI'NG~ LINER AND CEMENTING RECORD . ' CASING SE'I-rING DEPTH HOLE SIZE WT. PER FT. GRADE TOP Bo'FrOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 92# H-40 31' 113' 30" 260 sx Arctic Set (Approx.) . 9-5/8" 40# L-80 30' 5057' 12-1/4" 714 sx PF 'C', 360 sx Class 'G' 7" 26# L-80 28' 7679' 8-1/2" 170 sx Class 'G' , , 4-1/2" 12.6# L-80 7494' 8406' 6-1/8" 115 sx Class 'G' 241 Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 6 spf 2-7/8, 6.5#, 7396' - 7428' 7402' MD TVD MD TVD4-1/2", 12.6#, L-80 7199' A3 Sands 8162' - 8172' 7003' - 7012' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED A2 Sands 8162'- 8172'. 8191'- 8201' Frac'd with 179534# 16/20 Carbolite 8191' - 8201' 7029' - 7038' behind pipe. , , ,,, 27. PRODUCTION TEST Date First Production ' Method of Operation (Fiowing,' gas lift, etc.) .... August 11, 2001 Electric Submersible Pump 'bate of Test 'Hours Tested PRODUCTION FOR OIL-BBL "' GAS-MCF WATER-DEL CHOKE SIZE I GAS-OIL RATIO' 8/30/2001 5 TEST PERIOD 1826 463 37I 254 [~'lowTubing 3asing Pressure CALCULATED' ' OIL-BBL ' GAS-MCF WATER-BBL OIL GRAVITY-APl (coR'R) ' Press. 24-HOUR RATE ... 28. ' CORE DATA ..... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water, submit core chips. "' $£P 1 3 2001 Alaska 0il & Gas Cons. Commissior~ , ,,,, , ,, I A I Anchora0e Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top of Kuparuk 7834' 6713' TKU D 7834' 6713' TKUC 7978' 6839' TKUB 7991' 6850' TKUA 8140' 6983' TKA3 8143' 6986' TKA2 8184' 7023' Top of Miluveach 8262' 7094' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Post Rig Summary and FIT test 32.1 hereby certify that the foregoing, is tru~ and correct~ to the best of my knowledge l'-~ Signed TerrieHubble--~~ . Title TechnicalAssistant Date ~)-' "~/ MPC-24 201-094 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No. ! Approval No. , INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: MPC-24 Common Name: MPC-24 TeSt. Date ' "TeSt'Type Test'Depth (TMD). TeSt. Depth (TVD) i :. ::: AMW i : :i: : SUrface preSSure Leak Off Pressure (BHP) EMW 7/20/2001 FIT 5,056.0 (ft) 4,609.0 (ft) 9.50 (ppg) 480 (psi) 2,755 (psi) 11.50 (ppg) · Printed: 9/6/2001 1:30:11 PM BP EXPLORATION Page 1 of 7 Operations Summary Report Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: DRILL+COMPLETE Start: 7/12/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 7/12/2001 12:00 - 18:00 6.00 MOB P PRE Blow Down And Disconnect Steam, Water, And Mud Lines Then Disconnect Air Lines - Disconnect And Pull Back Electrical Cables - Pick Up All Steps And Landings - Install Towing Tongue On Pipe Shed And Move - Jack Up And Move Motor Shed - Remove Rock Washer From Pit Complex And Load - Install Towing Tongue On Second Pipe Shed And Back To End Of "C" Pad - Move Pit & Pump Complex - Pull Sub Base Off Of Hole. 18:00 - 00:00 6.00 MOB P PRE Lay Herculite - Set Sub Base Over Well Slot No. C-24 - Set Mud Pit & Pump Complex - Lay Matting Boards And Herculite For Rock Washer & Spot Same. 7/13/2001 00:00 - 10:00 10.00 MOB P PRE Lay Matting Boards For 1st Pipe Shed And Set - Remove Towing Gooseneck - Lay Matting Boards For Motor Complex And Set Unit - Hook Up Service Lines - Lay Matting Boards For 2nd Pipe Shed And Set - Remove Towing Gooseneck - Set Fuel Transfer Building & Spot Main Fuel Storage Tank - Spot Holding Tank For Cement Water - Install Western Gear Pipe Master Lay Down Machine Track To Rig Floor - Berm Around Rig - Spot Cuttings Tank & Spare Parts House - Pull Electrical Cables - Hook Up Utility Lines. 10:00 - 12:30 2.50 BOPSUR P SURF Rig Accepted For Well Work On MPC-24 At 11:00 Hours On 7/13/2001 - Start Mixing Spud Mud And Nipple Up 20" Riser 12:30 - 13:30 1.00 BOPSUR P SURF Hold Pre Spud Meeting - Organize And Hold A Complete Rig Evacuation Drill With All Personal 13:30 - 15:00 1.50 BOPSUR P SURF Continue To Nipple Up 20" Riser - Install Flow Line And Turnbuckles - Change Out Pipe Spinners On Iron Ruffneck 15:00 - 17:00 2.00 DRILL P SURF Hold Pre Job Safety Meeting - Rig Up Rig Floor - Bring BHA Tools To Rig Floor 17:00 - 18:30 1.50 DRILL P SURF Pick Up 5" HWDP And Stand Back In Mast 18:30 - 20:30 2.00 DRILL P SURF Hold Pre Job Safety Meeting - Pick Up And Make Up 12 1/4" Drilling Assembly 20:30 - 21:30 1.00 DRILL P SURF Rig Up Schlumberger Wire Line Services And Gryo Equipment & Preform Evacuation Drill With All Personal 21:30 - 22:30 1.00 DRILL P SURF Break Circulation And Check Surface Equipment For Leaks 22:30 - 00:00 1.50 DRILL P SURF Spud Well At 2200 Hours - Tag Bottom At 113' - Drill Ahead From 113' To 202' 7/14/2001 00:00 - 00:00 24.00 DRILL P SURF Directional Drill Ahead From 202' To 1,512' - Run Gryo With Gryo Data And Schlumberger On 90' Intervals 7/15/2001 00:00 - 08:00 8.00 DRILL i P SURF Continue To Directional Drill Ahead From 1,512' To 1,980' - Run Surface Gyro Every 90' As Required Per Well Plan With Schlumberger And Gyro Data. Due To Near-By Well Bore Interference. Actual Slide Time 1.5 Hours Actual Rotating Time 2.0 Hours 08:00 - 09:00 1.00 DRILL P SURF Circulate Hole Clean While Rigging Down Gryo Data Systems And Schlumberger Wire Line Services 09:00 - 12:00 3.00 DRILL P SURF POH With 5" Drill Pipe And BHA 12:00 - 13:30 1.50 DRILL 3 SURF SAFETY STAND DOWN -With Both Nabors Alaska Drilling Crews And Support Personal 13:30 - 15:30 2.00 DRILL ~ SURF Pick Up And Make Up BHA No.2 (MWD/LWD Assembly) - Printed: 7/30/2001 4:01:44 PM BP EXPLORATION Page 2 of 7 Operations Summary Report Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: DRILL+COMPLETE Start: 7/12/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 7/15/2001 13:30 - 15:30 2.00 DRILL P SURF Load MWD & Orient To Down Hole Motor 15:30 - 21:30 6.00 DRILL P SURF RIH Preform Madd Pass Log With Sperry Sun Tools - Log From 171' To 1,980' - Break Circulation 21:30 - 22:00 0.50 DRILL P SURF Take Rotational Check Shots With Sperry Sun 22:00 - 00:00 2.00 DRILL P SURF Directional Drill Ahead From 1,980' To 2,200' Actual Slide Time .5 Hours Actual Rotating Time 1.0 Hours 7/16/2001 00:00 - 13:00 13.00 DRILL P SURF Directional Drill Ahead From 2,200' To 3,607' 13:00 - 13:30 0.50 DRILL P SURF Circulate And Clean Hole Section - Pump Hi-Vis Sweep 13:30 - 15:00 1.50 DRILL P SURF Pre-Job Safety Meeting For Wiper Trip - POH To 1,640' 15:00 - 16:00 1.00 DRILL P SURF RIH To 3,607' -.Tag Bottom With NO FILL And NO PROBLEMS 16:00 - 00:00 8.00 DRILL P SURF Directional Drill Ahead From 3,607' To 4,454' 7/17/2001 00:00 - 10:00 10.00 DRILL P SURF Directional Drill Ahead From 4,454' To 5,026' 10:00 - 12:00 2.00 DRILL P SURF Circulate Hole Clean While Pumping Hi-Vis Sweeps 12:00 - 14:30 2.50 DRILL P SURF POH To 780' (SLM) - No Problems 14:30 - 16:30 2.00 DRILL P SURF RIH To 5,026' - No Problems And No Fill 16:30 - 17:00 0.50 DRILL P SURF Drill Ahead From 5,026' To 5,070' For Casing Tally 17:00 - 18:30 1.50 DRILL P SURF Circulate And Condition Mud For Surface Casing 18:30 - 21:00 2.50 DRILL P SURF POH With 5" Drill Pipe And HWDP 21:00 - 22:30 1.50 DRILL P SURF Lay Down BHA - Down Load Sperry Sun MWD/LWD Tools 22:30 - 00:00 1.50 CASE P SURF Hold Pre-Job Safety Meeting - Rig Up To Run 9 5/8" Casing 7/18/2001 00:00 - 01:00 1.00 CASE P SURF Hold Pre-Job Safety Meeting - Continue To Rig Up Casing Equipment 01:00 - 02:30 1.50 CASE P SURF Pick Up 9 5/8" Shoe Track And RIH - Make Up Franks Fill Up Tool And Circulate Thru Float Equipment - Continue To RIH With Casing 02:30 - 04:00 1.50 CASE N RREP SURF While Attempting To Fill Casing With Fill Up Tool The Rotary Hose Failed - The Top Drive IBOP Valve Was Opened And The Accuator DIDN"T Shift Valve To The Open Position - The Hose Failed At 3,500 Psi. - All Personal Was Removed From The Rig Floor - The Damage To The Hose Was Acessed To Verify That It Couldn't Fall Or Part By Nabors Toolpusher - The Bleeder Valve Was Opened And The Fluid Was Drained From The Rotary Hose - The Hose Was Removed From Top Drive And The Casing Fill Up Tool Was Laid Down. 04:00 - 12:30 8.50 CASE P SURF Continue To Pick Up And RIH With 123 Joints Of 9 5~8" 40lb. L-80 BTC Casing 12:30 - 14:00 1.50 CASE P SURF Circulate And Condition Mud 14:00 - 14:30 0.50 CASE P SURF Hold Pre-Job Safety Meeting With All Personal Reguarding Upcoming Cement Job And Plan Forward 14:30 - 17:30 3.00 CEMT P SURF Reciprocate Casing String --Turn Over To Haliburton - Pump 10 BBL. Water - Test Surface Equipment @ 3500 Psi. - Drop Bottom Plug - Continue To Pump 40 BBL. Water - Mix & Pump 50 BBLS. 10.4 PPG NSCI Alpha Spacer @ 5.2 BPM & 398 PSI. - Batch Up & Mix Type "L" Permafrost 10.7 PPG Lead Cement wi Yield Of 4.15 ft3/sk - Pump @ 8 BPM w/700 PSI. - Total Lead Cement Slurry Pumped 528 BBLS Or 714 sacks - After Pumping 400 BBLS. Of Lead Slurry Lost Returns For Brief Period When Cement Turned The Corner Regained Full Printed: 7/30/2001 4:01:44 PM BP EXPLORATION Page 3 of 7 Operations Summary Report Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: DRILL+COMPLETE Start: 7/12/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 7/18/2001 14:30 - 17:30 3.00 CEMT P SURF Returns After Pumping 460 BBLS. - Reduced Pumping Rate To 5 BPM - Follow Up Lead Cement w/Type "C" Premium Permafrost 15.8 PPG. Tail Cement w/Yield Of 1.15 ft3/sk- Tail Cement Job Was Pumped @ 3.0 BPM w/300 Psi. - Total Tail Cement Pumped 74 BBLS. Or 360 Sacks - Drop Top Wiper Plug - Haliburton Pumped 20 BBLS. Behind To Clear Lines Turned Over To Rig For Displacement - Displaced @ 7 BPM w/ 9.3 PPG. Spud Mud - Cement Back To Surface At 2615 Strokes. - Pumped 3,618 Strokes To Bump Plug - Total Cement Back To Surface 100 BBLS. - Final Circulation Pressure During Displacement @ 1175 PSI. - Continue To Pressure Up To 2,500 PSI. After Bumping Plug And Hold For 5 Min. - Bleed Pressure To 0 PSI. Check Floats (OK) Cement In Place @ 1710 Hours. 17:30 - 19:00 1.50 CEMT P SURF Rig Down Casing Tools - Back Out And Lay Down Landing Joint - Change Out Bails To Short Set - Clear Rig Floor 19:00 - 20:00 1.00 REMCM'~'P SURF Nipple Down Flow Line And 20" Riser 20:00 - 21:00 1.00 REMCM'~'P SURF Install FMC "A" Section And Orient - Energize Metal To Metal Seal And Test At 1000 Psi. (Tested Good) 121:00 - 00:00 3.00 REMCM'~'P SURF Nipple Up Tubing Spool - Install Second Annulus Valve - Install Double Studded Adaptor 11" 5M X 13 5/8" 5M - Set BOP On Well Head At Secure - Continue To Nipple Up BOP And Related Equipment. 7/19/2001 00:00 - 05:30 5.50 CEMT P SURF Continue To Nipple Up BOP And Related Equipment - Install Riser, Flow Line, Turnbuckles, Choke And Kill Lines - Tighten All Flanges - Pick Up Tools And Equipment In Celler Area. 05:30 - 07:30 2.00 CEMT N RREP SURF Lay Down Bad Kelly Hose And Clear Rig Floor 07:30 - 08:00 0.50 CEMT P SURF Install Test Plug In Lower Profile - Open Up Annulus Valve And Monitor Same During Test - Rig Up Test Equipment 08:00 - 14:30 6.50 CEMT P SURF Pressure Test 13 5/8 5M BOP - Test Choke Manifold, Upper And Lower Pipe Rams, Blind Rams, Full Opening Safety Valve, Dart Valve, Upper And Lower Top Drive IBOP Valves, Manual Valves And HCR Valves On Choke And Kill Line, Manual And Hydraulic Chokes All At 250 Psi. Low Pressure For 5 Minutes And At 4,000 Psi. High Pressure For 10' Minutes - Test Annular Element At 250 Psi. Low Pressure For 5 Minutes And 2,500 Psi. High Pressure For 10 Minutes - Perform Accumulator Test *NOTE* All Above Functions And Test's Was Witnessed By The AOGCC Field Represenitive Lou Grimauldi 14:30 - 15:00 0.50 CEMT P SURF Pull Test Plug - Install Wear Ring - Lay Down Test Joint - Clear Rig Floor Of Testing Equipment. 15:00 - 15:30 0.50 CEMT P SURF Hold Pre-Job Safety Meeting - Lock Out And Tag Out Draw Works And Mechanical Brake - Service Top Drive, Crown Sheaves, Traveling Blocks, Swivel Packing. 15:30 - 17:00 1.50 CEMT N RREP SURF Do Annual Inspection On Draw Works - Install Rotary Hose On Stand Pipe To Var¢o Top Drive 117:00 - 19:00 2.00 CEMT P SURF Slip And Cut 124' Of 1 3/8" Drilling Line - Set Crown-O-Matic 19:00 - 19:30 0.50 CEMT P SURF Check Integrity Of Other Circulating System Hoses - Pressure Test New Rotary Hose And Shock Hoses All The Way Back Rig Mud Pumps - Test At 4,000 Psi. or 10 Minutes. 19:30 - 22:30 3.00 CEMT P SURF Pick Up New 8 1/2" Drilling Assembly (BHA No.3) - Orient MWD To Mud Motor - Load Data Into MWD - Surface Test Printed: 7/30/2001 4:01:44 PM BP EXPLORATION Page 4 of 7 Operations Summa Report Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: DRILL+COMPLETE Start: 7/12/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 7/19/2001 19:30 - 22:30 3.00 CEMT P SURF Equipment 22:30 - 00:00 1.50 CEMT P SURF Pick Up 87 Joints Of 5" Drill Pipe From Pipe Shed And RIH 7/20/2001 00:00 - 02:00 2.00 CEMT P SURF Continue To Pick Up 87 Joints Of 5" Drill Pipe From Pipe Shed And RIH 02:00 - 03:00 1.00 CEMT P SURF RIH With 5" Drill Pipe Out Of Mast To 4,700' 03:00 - 05:00 2.00 CEMT P SURF Make Up Top Drive Perform Mad Pass Log At 200' Per Hour From 4,700' To 4,970' - Tag Cement At 4,965' And Drill To 4,970' 05:00 - 05:30 0.50 CEMT P SURF Circulate Bottoms Up 05:30 - 07:00 1.50 CEMT P SURF Check Slow Pump Rates - Rig Up And Test Casing For 30 Minutes (Test Good) 07:00 - 07:30 0.50 CEMT P SURF Continue To Drill Cement Tag Wiper Plugs At 4,971' And Float Collar At 4,973' - Drill Shoe Track Cement And Float Shoe At 5,056' - Wash And Ream Out 12 1/4" Rat Hole To 5,070' 07:30 - 08:00 0.50 DRILL P INT1 Drill Ahead From 5,070' To 5,100' - New Hole Section For FIT 08:00 - 08:30 0.50 DRILL P INT1 Circulate And Condition Mud 08:30 - 09:30 1.00 DRILL P INT1 Perform Formation Integrity Test With 9.5 PPG Mud While Applying 500 Psi. To Formation For An Equivalent Mud Weight Of 11.59 PPG 09:30 - 22:30 13.00 DRILL P INT1 Directional Drill Ahead From 5,100' To 6,522' 7/21/2001 00:00 - 01:00 1.00 DRILL P INT1 Continue To Circulate Bottoms Up At 6,522' 01:00 - 03:00 2.00 DRILL P INT1 Hold Pre-Job Safety Meeting - Monitor Well (Static) - POH To 9 5/8" Casing Shoe Pull Slow Due To Swabbing BHA Appeared To Be Balled Up Screw Into String And Rotate - Continue To POH To Shoe - Hole Taking Correct Amount Of Fluid - Monitor Well At Shoe (Static) 03:00 - 04:00 1.00 DRILL P INT1 Circulate Into Trip Tank While Servicing Top Drive, Turning Flow Line Flow Show Paddle, Remove Plastic Wrap From Rotary Hose. 04:00 - 05:00 1.00 DRILL P INT1 RIH With No Problems To 6,522' - No Fill 05:00 - 20:00 15.00 DRILL P INT1 Drill Ahead From 6,522' To 7,690' (TD For 7" Casing) 20:00 - 22:00 2.00 DRILL P INT1 Circulate And Condition Mud While Pumping Hi-Vis Sweeps 22:00 - 23:30 1.50 DRILL P INT1 Hold Pre-Job Safety Meeting - Monitor Well (Static) - Pull 5 Stands - Pump Dry Job - POH To 9 5/8" Casing Shoe With No Problems - Hole Taking Correct Amount Of Fluid - Monitor Well At Shoe (Static) 23:30 - 00:00 0.50 DRILL P INT1 RIH (Wiper Trip) - No Problems 7/22/2001 00:00 - 01:00 1.00 DRILL P INT1 Continue To RIH From 6,430' To 7,690' No Problems And No Fill 01:00 - 03:00 2.00 DRILL P INT1 Circulate And Pump Sweeps Until Hole Clean - 292 Units Of Trip Gas On Bottoms Up 03:00 - 09:00 6.00 DRILL P INT1 Monitor Well For "No Flow" (Static) ~ Pump Dry Job - POH Laying Down 5" Drill Pipe To 1,365' 09:00 - 11:00 2.00 DRILL N RREP INT1 Repair Varco Iron Ruffneck 11:00 - 12:00 1.00 DRILL P INT1 Continue To Lay Down 5" Drill Pipe 12:00 - 14:00 2.00 DRILL P INT1 Lay Down BHA & Down Load Sperry Sun MWD/LWD Tools 14:00 - 14:30 0.50 DRILL P INT1 Clear Rig Floor Of BHA Tools And Misc. Equipment 14:30 - 18:00 3.50 CASE N DPRB INT1 Attempt To Pull Wear Bushing - Unable To "J" Into With Pulling Tool - Try With 2 Other Tools 18:00 - 19:30 1.50 CASE P INT1 Change Pipe Rams In Top Gate To 7" 19:30 - 20:00 0.50 CASE N DPRB INT1 Make Up Baker Oil Tools "Spear" & Pull Wear Bushing - L/D Fishing Tools & Clear Rig Floor 20:00 - 21:00 1.00 CASE P INT1 Rig Up And Test Door Seals At 2,000 Psi. (Tested Good) Printed: 7/30/2001 4:01:44 PM BP EXPLORATION Page 5 of 7 Operations Summa Report Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: DRILL+COMPLETE Start: 7/12/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 7/22/2001 21:00 - 23:00 2.00 CASE P INT1 Hold Pre-Job Safety Meeting - Change Bails To Long Set - Rig Up Casing Tools And Equipment - Hold Pre-Job Metting And Pick Up Franks Casing Fill Up Tool. 23:00 - 00:00 1.00 CASE P INT1 Make Up 7" Float Equipment - Circulate Thru Shoe Track - Continue To RIH With 7" Casing Per Program 7/23/2001 00:00 - 05:00 5.00 CASE P INT1 Continue To RIH With 7" Casing Per Program To 9 5/8" Casing Shoe 05:00 - 06:00 1.00 CASE P INT1 Circulate Bottoms Up At 9 5~8" Casing Shoe - No Gas 06:00 - 09:00 3.00 CASE P INT1 Continue To RIH With 7" Casing To 7,678' - No Problems 09:00 - 09:30 0.50 CASE P INT1 Hold Pre-Job Safety Meeting - Remove Franks Casing Fill Up Tool From Top Drive And Lay Down - Make Up Haliburton Plug Droping Head And Hook Up Cement Line. 09:30 - 10:30 1.00 CEMT P INT1 Circulate Two Bottoms Up And Condition Mud For Cement Job Hold Pre-Job Safety Meeting With All Personal Reguarding Upcoming Cement Job. - 328 Units Of Gas At Bottoms Up. 10:30 - 12:30 2.00 CEMT P INT1 Reciprocate Casing String Through Out Cement Job -Turn Over To Haliburton - Pump 5 BBL. Water - Test Surface Equipment @ 3500 Psi. - Continue To Pump 15 BBL. Water - Drop Bottom Wiper Plug - Mix & Pump 35 BBLS. 1.1.5 PPG NSCI Alpha Spacer @ 5.2 BPM & 398 PSI. - Batch' Up & Mix Premium 15.8 PPG. Tail Cement wi Yield Of 1.15 ft3/sk - Tail Cement Job Was Pumped @ 5.0 BPM w/600 Psi. - Total Tail Cement Pumped 35 BBLS. Or 170 Sacks - Drop Top Wiper Plug - Haliburton Pumped 5 BBLS. Behind To Clear Lines Turned Over To Rig For Displacement - Displaced @ 6 BPM w/ 10.5 PPG. Mud - Pumped 2,857 Strokes To Bump Plug - Final Circulation Pressure During Displacement @ 550 PSI. - Continue To Pressure Up To 2,500 PSI. After Bumping Plug And Hold For 5 Min. - Bleed Pressure To 0 PSI. Check Floats (OK) Cement In Place @ 1200 Hours. 12:30 - 14:00 1.50 CEMT P INT1 Back Out Landing Joint And Lay Down - Rig Down Casing Tools And Equipment - Change Out Bales To Short Set - Clear Rig Floor. 14:00 - 15:00 1.00 CEMT P INT1 Install 7" Casing Pack Off And Test At 5,000 Psi. (Tested Good) 15:00 - 16:00 1.00 CEMT P INT1 Install 3 1/2" X 6" Variable Ram Blocks In Top Gate 16:00 - 17:00 1.00 CEMT P INT1 Change Top Drive Saver Sub And Bell Guide To Accommodate 3 1/2" Drill Pipe 17:00 - 18:30 1.50 CEMT P INT1 Pressure Test Top Set Pipe Rams, 3 1/2 IF Floor Vave And Dart Valve At 250 Psi. Low Pressure For 5 Minutes And 4000 Psi. High Pressure For 10 Minutes. 18:30 - 19:00 0.50 CEMT ~P INT1 Rig Down Test Equipment And Pull Test Plug - Install Wear Bushing And Energize Lock Down Studs 19:00 - 22:00 3.00 CEMT P INT1 LAY Down 18 Stands Of 5" Drill Pipe In Mouse Hole 22:00 - 00:00 2.00 DRILL P PROD1 Pick Up BHA No. 4 New 6 1/8" Drilling Assembly 7/24/2001 00:00 - 03:00 3.00 DRILL P PROD1 Finish making up 6-1/8" bha. Orient and load MWD/LWD. Surface test. 03:00 - 11:00 8.00 DRILL P PROD1 Tih picking up 3-1/2" drill pipe. Stand back 9 stands in derrick to drill open hole. Tag float collar. 11:00 - 12:00 1.00 EVAL P PROD1 Break circulation and test 7" casing 4000 psi. Record for 30 minutes on chart recorder. Good test. 12:00 - 14:00 2.00 DRILL P PROD1 Drill float collar, cement, float shoe and tag bottom 7690'. 14:00 - 15:00 1.00 DRILL P PROD1 Displace old 10.5 ppg mud in well with new 11.5 ppg mud. Printed: 7/30/2001 4:01:44 PM BP EXPLORATION Page 6 of 7 Operations Summa Report Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: DRILL+COMPLETE Start: 7/12/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 7/24/2001 15:00 - 15:30 0.50 DRILL P PROD1 Drill 20' new formation 7710'. 15:30 - 16:00 0.50 DRILL P PROD1 Circulate bottoms up 11.5 mud wt in and out. 16:00 - 16:30 0.50 DRILL P PROD1 Perform FIT with 11.5 ppg with 1130 psi. EMW=14.8 ppg 16:30 - 00:00 7.50 DRILL P PROD1 Directional drill 7710-7842'. 10-15 K WOB; 60 Rpms, 4-5000 Ft lbs torque; 233 gpm; 2900 psi/2650psi(on & off bottom.) 7/25/2001 00:00 - 08:00 8.00 DRILL P PROD1 Directional drill 7842-8406(TD)'. 10-15 K WOB; 60 Rpms, 4-5000 Ft lbs torque; 233 gpm; 3100 psi/2750psi(on & off bottom.) 08:00 - 09:30 1.50 DRILL P PROD1 Circulate and condition mud for short trip. 09:30 - 10:00 0.50 DRILL P PROD1 Short trip to casing shoe-no problems. 10:00 - 10:30 0.50 DRILL P PROD1 Monitor well 15 minutes and TIH. No problems. 10:30 - 12:30 2.00 DRILL P PROD1 Circulate and condition mud to run RFT's. 1078 units of gas on bottoms up. 12:30 - 15:00 2.50 DRILL P PROD1 Pump out 8 stands to casing shoe. Monitor well for 15 minutes-static. Pump 12 more stands out and monitor well-static. Pump dry job. 15:00 - 20:30 5.50 DRILL P PROD1 Pooh monitoring well every 20 stands 20:30 - 00:00 3.50 DRILL P PROD1 RU Schlumberger RFT & wireline. One pressure sample taken at 7983' (6900 TVD), 3293 psi, 9.2 EMW. Pad would not retract on tool. Pull 1000 Ibf over line weight and pad retracted. POOH for tool failure. Call shop for back-up tool to be readied. 7/26/2001 00:00 - 05:00 5.00 DRILL N DFAL PROD1 RFT tool failure. Probe would not retract. Pulled tool free. Pooh and change out tool. 05:00 - 11:00 6.00 DRILL P PROD1 Run in hole with new tool. Took 22 pressure points. The last 3 points were taken in the Kalubik. The formation was too tight to get an accurate psi. The last point was at 7782'. The tool was stuck briefly, but the operator and engineer managed to pull it free. Pooh and rig down Schlumberger. Maximum formation psi was in the A3 sand(3970 psi at 8164'/7005=10.9 PPg) 11:00 - 12:00 1.00 DRILL P PROD1 POOH w/wireline & RFT. Lost total 14 bbl mud. 12:00 - 12:30 0.50 DRILL P PROD1 RD Schlumberger wireline unit. 12:30 - 16:00 3.50 DRILL P PROD1 PU BHA & Rill to 8406'. No fill. 1535 units of gas at bottoms up. 16:00 - 18:00 2.00 DRILL P PROD1 Circulate & condition mud. 18:00 - 19:30 1.50 DRILL P PROD1 Monitor well for 10 mins. Pump out 11 stands to 7" casing shoe. 19:30 - 23:00 3.50 DRILL P PROD1 Pump weighted pill. POH & monitor every 30 stands. Rabbit DP w/1 15/16". 23:00 - 23:30 0.50 DRILL P PROD1 LD BHA. 23:30 - 00:00 0.50 DRILL P PROD1 Clear rig floor. Change elevator bails. 7/27/2001 00:00 - 01:30 1.50 CASE P PROD1 Finish rigging up to run 4-1/2" liner. 01:30 - 03:30 2.00 CASE P PROD1 M/u 21 jts 4-1/2" 12.6# L-80 IBT liner with hanger and ZXP packer. Circulate capacity of liner. 03:30 - 09:30 6.00 CASE P PROD1 Tih with liner on 3-1/2 drill pipe. Break circulation at casing shoe and rig up cement manifold. 09:30 - 11:30 2.00 CASE P PROD1 Break circulation slow and bring rate up to 5 bpm with no losses with 2000 psi. Circulate 3 b/u and reciprocate pipe. 172K up / 135K down. Started mixing latex cement at 1030. 11:30 - 12:30 1.00 CASE P PROD1 Pre job safety meeting. Pump 10 bbls water. Test lines 4000 psi. Pump 20 bbls 12.8 spacer and 25 bbls of 15.6 ppg Latex cement. Flush lines and switch to rig pumps. Pump 15 bbls Printed: 7/30/2001 4:01:44 PM BP EXPLORATION Page 7 of 7 Operations Summa Report Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: DRILL+COMPLETE Start: 7/12/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 712712001 11:30 - 12:30 1.00 CASE P PROD1 seawater followed by 48 bbls mud. Slow down pumps to 3 bpm and plug latch up and shear. Bumped plug to 3500 psi. Cement in place at 12:15. Floats held. 12:30 - 13:00 0.50 CASE P PROD1 Set down 35K and release with 20 right hand turns. Pressure up 800 psi and pick up to release from hanger. Once running tool was free of hanger pressure dropped off. 13:00 - 13:30 0.50 CASE P PROD1 Circulate hole clean. 10 bbls of cement to surface. 13:30 - 14:00 0.50 CASE P PROD1 Test ZXP packer and hanger 3500 psi for 30 minutes on chart recorded. Good test. 14:00 - 19:30 5.50 CASE P PROD1 Circulate and displace well with seawater. 19:30 - 00:00 4.50 CASE P PROD1 Mix & pump weighted NaCI pill (dry job). POOH LDDP. Printed: 7/30/2001 4:01:44 PM BP EXPLORATION Page 1 of 1 Operations Summa Report Legal Well Name: MPC-24 Common Well Name: MPC-24 Spud Date: 7/13/2001 Event Name: COMPLETION Start: 8/19/2001 End: 8/22/2001 Contractor Name: NABORS ., Rig Release: 8/23/2001 Rig Name: NABORS/~I~- L.{ ~ Rig Number: Z2~E L.~...~ Date From -To Hours Activity Code NPT Phase Description of Operations 8/20/2001 21:00 - 00:00 3.00 RIGU P COMP MOVED RIG FROM L-11AND STARTED RIGGING UP. 8/21/2001 00:00 - 06:00 6.00 RIGU P COMP MOVE FROM L-11 TO C-24 & RIG UP. ACCEPTED RIG @ 06:00. 06:00 - 08:00 2.00 RIGU P COMP SPOT & BERM TIGER TANK. HOOK UP LINES TO TREE. 08:00 - 10:00 2.00 RIGU P COMP LOAD PITS W/SEAWATER & WT. UP TO 8.7 PPG. PULL BPV. 10:00 - 10:30 0.50 KILL P COMP PRESS. TEST LINES TO 3500 PSI. 10:30 - 12:30 2.00 KILL P COMP CIRC. TO KILL WELL. MONITOR. TBG. 40 PSI. CSG. 70 PSI. 12:30 - 14:30 2.00 KILL P COMP WT. UP PITS & WELL FLUID TO 9.2 PPG. KILL WELL. 14:30 - 16:30 2.00 WHSUR P COMP SET TWC & TEST TO 3500 PSI. ND TREE. 16:30 - 19:30 3.00 BOPSUF; P COMP NU BOPE. 19:30 - 21:00 1.50 BOPSUF; P COMP BODY TEST BOPE. LP 250. HP 3500 PSI. WITNESSING WAIVERED BY J. JONES (AOGCC). 21:00 - 22:00 1.00 PULL P COMP PULLED TWC. 22:00 - 00:00 2.00 PULL P COMP MU LANDING JT. BOLDS. PULL ON HANGER UP TO 175K. WORK PIPE. WT. UP TO 9.4 PPG. CONT. TO WORK PIPE. 8/22/2001 00:00 - 01:30 1.50 PULL P COMP ATTEMPT TO PU HANGER TO FLOOR. WORK PIPE. WT. UP MUD TO 9.4 PPG. CONT. TO WORK PIPE. PIPE CAME FREE @ 185K. 01:30 - 02:30 1.00 PULL P COMP LID HANGER & LANDING JT. MONITOR WELL. 02:30 - 06:00 3.50 PULL P COMP POOH L/D 4 1/2" TBG. 06:00 - 06:30 0.50 PULL P COMP SERVICE RIG. 06:30 - 11:30 5.00 PULL P COMP POOH LID 4 1/2" TBG. 11:30 - 13:00 1.50 RUNCOr~I:) COMP CLEAR FLOOR. R/U TO RUN ESP. 13:00 - 19:00 6.00 RUNCOI~I:' COMP P/U MOTOR/PUMP & SERVICE. PULL CABLE AND SECURE TO ESP. 19:00 - 00:00 5.00 RUNCOr~I:' COMP RIH W/ESP & 2 7/8" TBG. I 18/23/2001 00:00 - 02:00 2.00 RUNCOr~I:' COMP COMPLETE RIH W/ESP & 2 7/8" TBG. 02:00 - 05:00 3.00 RUNCOI~I:' COMP M/U HANGER. INSTALL PENETRATOR. SPLICE EFT CONNECTOR. TESTED OK. LAND HANGER. RILDS. P/U WT. 62K. SIC WT. 49K. INSTALL & TEST TWC. 05:00 - 07:00 2.00 RUNCOr~!:) COMP ND BOPE. 07:00 - 09:00 2.00 RUNCOI~I:' COMP NU TREE & TEST TO 5000PSI. 09:00 - 10:30 1.50 RUNCOI~I:' COMP FINAL TEST ON PENETRATOR FAILED. 10:30 - 11:30 1.00 RUNCOI~I:' COMP NDTREE. 11:30- 13:00 1.50 RUNCOI~I:' COMP NU BOPE. 13:00 - 13:30 0.50 RUNCOr~I:' COMP BODY TEST BOPE. 250/3500 PSI. 13:30 - 15:30 2.00 RUNCOr~F' COMP P/U LANDING ,.IT. M/U HANGER. BOLDS. PULL HANGER TO FLOOR. TEST ESP EQUIPMENT. FIELD CONNECTION FAILED. 15:30 - 17:30 2.00 RUNCOr~I:' COMP REPLACE FIELD CONNECTION. PLUG IN & TEST. 17:30 - 18:00 0.50 RUNCOI~I:' COMP LAND HANGER. RILDS. SET TWC & TEST. 18:00 - 19:30 1.50 RUNCOI~I:' COMP ND BOPE. 19:30 - 20:30 1.00 RUNCOI~F' COMP NU TREE AND TEST TO 5000 PSI. 20:30 - 21:00 0.50 RUNCOI~I:' COMP PUMP FLUID MN. 7" CSG. TEST ESP. TESTED GOOD. 21:00 - 22:00 1.00 RUNCOkI:' COMP PULL TVVC. SET BPV. RELEASED RIG @ 22:00 HRS. 22:00 - 00:00 2.00 RIGD P COMP RIG DOWN. Printed: 8/27/2001 10:10:28AM Well: MPC-24 Rig Accept: 07-13-01 Field: Milne Point Unit / Kuparuk River Sands Rig Spud: 07-13-01 APl: 50-029-23020 Rig Release: 07-28-01 Permit: 201-094 Drilling Rig: 22E POST - RIG WORK 07/31/01 Pulled BPV, Pulled RHC plug, drifted tubing with 3.40" to 8307' SLM. 08/02/01 RU SWS pressure tested equipment. Start down tubing with 3-3/8" 6 SPF 60 degrees, big hole charges. Able to make it into the liner but was unable to get past 8070' MD, There was heavy brine left in 4.5" liner and they were unable to work guns deeper. No by-pass with the larger guns. POH and lay down equipment until morning. Will attempt with 2-7/8" guns. 08/03101 RU SWS pressure tested equipment. Start down tubing with 2-7/8", 6 SPF, 60 degrees big hole charges. Went through liner and tagged TD 8315' ELMD. Made a CCL / GR pass through tail pipe assembly. This log will be used as the primary log for future perforations. The E-Line unit was equipped with special measuring system. But it is normally used with there larger line. Made pass through perforated intervals and tied into CCL / GR Pass, adjusted perforation depths to log. Logged into place with first 10' gun CCL to top shot 7.9' CCL shooting depth 8154.1' interval A2 Sands shot from 8191' - 8201', pressure up on the tubing to 1100 psi. Gun fired pressure spiked to 1300 psi and returned to 1100 psi. POH all shots fired. Run in hole with second 10' gun logged into place. CCL shot depth at 8154.1', CCL to top shot 7.9' interval A3 Sands 8162' - 8172' POH all shots fired. 20' perforations shot in the Kuparuk. Well ready for frac. Final tubing pressure 1100 psi. 08/04101 Pump 152 BBL 20# slick at 52 BPM 3930 psi, broke at 7642 psi. ISIP = 2393 psi, 225 BBL scour stage at 25 BPM 3510 psi. ISIP 2558 psi calc total friction at 450 psi, pump 150 BBL Data Frac at 25 BPM, 3382 psi. ISIP 2518 psi, closure time = 9 minutes with 50% fluid efficiency. Pumped 115 BBL m YF140D pad. Ramped sand from 1.0 PPA to 10.0 PPA Achieved TSO. Screened out last 7 BBL of displacement. Placed 179534 # Proppant behind pipe. 3100 # of Proppant left in Wellbore. 75% of Treesaver cups recovered. Left well shut in for Coil Tubing. 08/07/01 & 08108/01 RU DS CTU # 5. RIH with 2.25" reversing nozzle. Wash tubing while RIH. Tag sand top at 7470' CTD, Reverse out to 8151' CTD, Tag, PUH jet through, plug nozzle at 8165', pull WT, Free coil, PUH to clear nozzle, RBIH tag high at 8030' CTD. Reverse to 8165' CTD (top perfs) plug nozzle, free up coil, RBIH to tag high at 8035' CTD, difficult to make hole. Break through bridge and reverse to 8298' CTD. Pre Frac eline tag at 8315', minimum 97' of RAT hole, consistent 1:1 returns during clean out, POOH. Weekly BOP tests. Freeze Protect well to 2500' with 50/50 Methanol. 08/17/01 Cut tubing at 7396' with 3-7/16" jet cutter, 4' above packer. 04-Sep-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPC-24 Gyro Dear Dear SidMadam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 'MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED SEP 0 7 2001 Alaska 0il & Gas Cons. Commis,~ion Ancho~e DEFINITIVE Milne Point Unit Alaska Drilling & Wells Milne Point MPC, Slot MPC-24 MPC-24_ Gyro Job No. AKZZ11117, Surveyed: 25 July, 2001 SURVEY REPORT 5 September, 2001 Your Reft APi500292302000 Surface Coordinates: 6029452.34 N, 558013.45 E (70° 29' 27.9035" N, Kelly Bushing: 44.80ft above Mean Sea Level 149°31'32.6502"W) I~'R iL LI NI3 SERVICES A Halliburton Company Survey Ref: svy9927 Sperry-Sun Drilling Services Survey Report for MPC-24_Gyro Your Ref: API500292302000 Job No. AKZZ11117, Surveyed: 25 July, 2001 DEFINITIVE Milne Point Unit Alaska Drilling & Wells Milne Point MPC Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (fi) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -44.80 0.00 0.00 N 0.00 E 6029452.34 N 558013.45 E 100.00 0.300 308.500 55.20 100.00 0.16 N 0.20 W 6029452.50 N 558013.24 E 176.88 0.300 288.500 132.08 176.88 0.35 N 0.55 W 6029452.69 N 558012.89 E 267.22 0.600 298.200 222.42 267.22 0.65 N 1.19 W 6029452.98 N 558012.25 E 356.35 0.600 64.800 311.54 356.34 1.07 N 1.18 W 6029453.40 N 558012.26 E 444.61 2.100 74.900 399.78 444.58 1.69 N 0.80 E 6029454.03 N 558014.23 E 534.05 2.800 87.500 489.13 533.93 2.21 N 4,56 E 6029454.59 N 558017.99 E 624.60 2.900 91.600 579.57 624.37 2.24 N 9.06 E 6029454.65 N 558022.49 E 714.60 5.000 105.000 669.36 714.16 1.16 N 15,12 E 6029453.62 N 558028.57 E 808.63 5.500 106.900 762.99 807.79 1.21 S 23,39 E 6029451,32 N 558036.85 E 902.60 5.600 99.200 856.52 901.32 3.25 S 32.23 E 6029449.34 N 558045.70 E 996.26 7.900 101.500 949.53 994.33 5.26 $ 43.05 E 6029447.41 N 558056.54 E 1086.21 8.900 103.300 1038.51 1083.31 8.10 S 55.88 E 6029444.68 N 558069.39 E 1179.62 10.500 113.700 1130.59 1175.39 13.18 S 70.71 E 6029439.71 N 558084.26 E 1273.08 12.200 113.000 1222.22 1267.02 20.46 S 87.60 E 6029432.56 N 558101.20 E 1366.82 14.100 105.800 1313.50 1358.30 27.44 S 107.70 E 6029425.74 N 558121.36 E 1460.84 16.600 110.300 1404.16 1448.96 35.22 S 131.32 E 6029418.14 N 558145.04 E 1555.36 16.900 110.900 1494.67 1539.47 44.81 S 156.82 E 6029408.76 N 558170.62 E 1649.03 16.100 110.700 1584.49 1629.29 54.26 S 181.69 E 6029399.50 N 558195.56 E 1742.52 18.500 116.300 1673.75 1718.55 65.41 $ 207.12 E 6029388.55 N 558221.07 E 1836.02 18. 700 117.800 1762.36 1807.16 78.97 S 233.68 E 6029375.19 N 558247.74 E 1929.94 18.700 115.400 1851.33 1896.13 92.45 S 260.60 E 6029361.92 N 558274.76 E Dogleg Rate (°/100ft) 0.300 0.136 0.341 1.203 1.714 0.983 0.251 2.533 0.563 0.799 2.472 1.149 2.534 1.825 2.672 2.944 0.366 0.856 3.122 0.555 0.819 Vertical Section Comment 0.00 -0.26 -0.64 -1.30 -1.59 -0.65 1.62 4.75 9.78 17.27 24.92 33.94 44.96 58.98 76.02 95.09 117.20 141.92 166.09 191.88 220.17 248.66 AK-1 BP._HG All data is-in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North, Vertical depths are relative to Well. Northings and Eastings are relative to Well, Magnetic Declination at Surface is 26.261° (13-Jul-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 135,470° (True), Based upon Minimum Curvature type calculations, at a Measured Depth of 1929,94ft,, 5 September, 2001 - 9:03 Page 2 of 3 Dr/I/Quest 2. 00. 08. 005 Sperry-Sun Drilling Services Survey Report for MPC-24_Gyro Your Ref: API500292302000 Job No. AKZZ11117, Surveyed: 25 July, 2001 Milne Point Unit The Bottom Hole Displacement is 276.51ft., in the Direction of 109.534° (True). Alaska Drilling & Wells Milne Point MPC Survey tool program for MPC-24_Gyro From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 1929.94 1896.13 Survey Tool Description AK-1 BP_HG 5 September, 2001 - 9:03 Page 3 of 3 DrillQuest 2.00. 08.005 04-Sep-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPC-24 Dear Dear SidMadam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD 'MD 8,406.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED SEP 0 7 2001 Alaska Oil & Gas Cons. Commission Anchorage Milne Point Unit Alaska Drilling & Wells Milne Point MPC, Slot MPC-24 MPC-24 Job No. AKZZ11117, Surveyed: 25 July, 2001 DEFINITIVE SURVEY REPORT 5 September, 2001 Your Ref: API500292302000 surface Coordinates: 6029452.34 N, 558013.45 E (70° 29' 27.9035" N, Kelly Bushing: 44.80ft above Mean Sea Level 149°31'32.6502'W) A Halliburton Company Survey Ref: svy9928 Milne Point Unit Measured Depth (~t) Incl. Azim. Sub-Sea Depth (ft) 1929.94 18.700 115.400 1851.33 1965.09 19.010 114.330 1884.59 2056.56 23.620 118.360 1969.78 2150.23 23.910 118.480 2055.51 2244.50 26.180 118.060 2140.91 Vertical Depth (fi) 1896.13 1929.39 2014.58 2100.31 2185.71 2338.80 28.900 117.850 2224.52 2269.32 2432.69 31.620 120,050 2305,61 2350.41 2526.66 31.670 116.920 2385.62 2430.42 2620.92 29.850 116.120 2466.61 2511.41 2715.22 29.620 115.690 2548.50 2593.30 2809.26 29.230 114.620 2630.40 2675.20 2903.06 30.820 115.500 2711.61 2756.41 2997.56 31.110 119.080 2792.65 2837.45 3090.90 31.260 119.260 2872.51 2917.31 3184.70 31.060 115.990 2952.78 2997.58 3278.65 30.740 117.830 3033.40 3078.20 3372.60 30.710 118.020 3114.16 3158.96 3466.19 30.870 117.490 3194.56 3239.36 3561.16 30.710 119.200 3276.14 3320.94 3653.78 30.800 118.990 3355.74 3400.54 Sperry-Sun Drilling Services Survey Report for MPC-24 Your Ref: API500292302000 Job No. AKZZ11117, Surveyed: 25 July, 2001 3748.69 30.930 118.920 3437.20 3482.00 3842.27 31.060 118.860 3517.42 3562.22 3935.20 31.150 118.200 3596.99 3641.79 4029.04 31.070 118.760 3677.34 3722.14 4122.75 31.050 118.920 3757.61 3802.41 4216.51 30.890 118.230 3838.00 4311.15 30.640 118.490 3919.33 4404.96 31.090 117.500 3999.85 4499.06 31.430 117.990 4080.29 4593.75 30.160 118.410 4161.63 3882.80 3964.13 4044.65 4125.09 4206.43 Local Coordinates Global Coordinates Northlngs Eaatlnga Northlngs Eastings (ft) (ft) (ft) (ft) 92.45 S 260.60E 6029361.92 N 558274.76E 97.23 S 270,90E 6029357.23 N 558285.10 E 112.08 S 300.62 E 6029342.61N 558314.93 E 130.05 S 333.82 E 6029324.90N 558348.27 E 148.94 $ 368.97 E 6029306.28 N 558383.57 E 169.37 S 407.48E 6029286.15 N 558422.24 E 192.30 S 448.85E 6029263,54 N 558463.79 E 215.81 S 492.17 E 6029240.38 N 558507.29 E 237.34S 535.30E 6029219.18 N 558550.59 E 257.78 $ 577.37 E 6029199.08 N 558592.82 E 277.42 S 619.19 E 6029179.76 N 558634.78 E 297.30 S 661.70 E 6029160.21N 558677.45 E 319.59 S 704.89 E 6029138.26 N 558720.81 E 343.15 $ 747.09 E 6029115.03 N 558763.20 E 365.65 $ 790.08E 6029092.87 N 558806.36 E 387.48 S 833.10 E 6029071.37 N 558849.54 E 409.96 S 875.51E 6029049.22N 558892.13 E 432.27 $ 917.90E 6029027.25 N 558934.70 E 455.35 S 960.69 E 6029004.50 N 558977.66 E 478.38 $ 1002.07 E 6028981.80 N 559019.22 E 501.95 S 1044.68 E 6028958.56 N 559062.01 E 525.23 S 1086.87 E 6028935.60 N 559104.38 E 548.16 S . 1129.05 E 6028913.00 N 559146.74 E 571.28 S 1171.67 E 6028890.22 N 559189.54 E 594.60 S 1214.02E 6028867.23 N 559232.07 E 617.68 S 1256.39 E 6028644.48 N 559274,62 E 640.67 S 1298.99E 6028821.82 N 559317.40 E 663.26 $ 1341.48E 6028799.56 N 559360.07 E 685.99 S 1384.70 E 6028777.17 N 559403.46 E 708.90 S 1427.42 E 6028754.60 N 559446.36 E DEFINITIVE Alaska Drilling & Wells Milne Point MPC Dogleg Vertical Rate Section (°/lOOfl) 248.66 1.321 259.29 5.285 290.72 0.314 326.81 2.415 364.93 2.886 406.50 3.128 451.86 1,748 499.00 1.979 544.59 0.333 588.66 0.696 631.99 1.759 675.98 1.973 722.16 0.189 768.55 1.816 814.73 1.062 860.46 0.108 906.23 0.337 951.87 O.937 998.32 0.151 1043.76 0.142 1090.45 0.143 1136.63 0.379 1182.56 0.320 1228.93 0.091 1275.25 0.415 1321.42 0.299 1367.68 0.723 1413.59 0.451 1460.10 1.360 1506.39 Comment Tie On Point AK-6 BP_IFR-AK 5 September, 2001 - 9:23 Page 2 of $ DrillQuest 2. 00. 08.005 Sperry-Sun Drilling Services Survey Report for MPC-24 Your Ref: API500292302000 Job No. AKZZ11117, Surveyed: 25 July, 2001 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 4687,46 30,000 118.970 4242.72 4287.52 4781.56 29.640 115.860 4324.36 4369.16 4875.90 29.030 115.590 4406.60 4451.40 4970.32 29.430 116.930 4489.00 4533.80 5022.81 29.400 118.020 4534.73 4579.53 5136.59 29.690 117.570 4633.71 4678.51 5230.45 29.410 116.820 4715.36 4760.16 5323.99 30.490 121.200 4796.42 4841.22 5417.77 30.720 121.880 4877.14 4921.94 5511.82 30.310 121.460 4958.16 5002.96 5605.39 31.440 124.790 5038.47 5083.27 5699.68 33.190 130.130 5118.17 5162.97 5793.05 35.160 134.110 5195.43 5240.23 5887.16 36.450 139.250 5271.77 5316.57 5981.41 38.430 145.170 5346.62 5391.42 6075.09 40.480 152.350 5418.99 5463.79 6168.78 43.270 159.830 5488.79 5533.59 6262.84 47.050 163.100 5555.11 5599.91 6357.02 48.910 164.080 5618.15 5662.95 6450.85 53.920 164.910 5676.65 5721.45 6545.28 56.320 164.130 5730.65 5775.45 6638.42 56.030 163.230 5782.50 5827.30 6732.18 55.490 162.190 5835.25 5880.05 6826.11 52.940 160.930 5890.18 5934.98 6919.97 50.100 161.440 5948.57 5993.37 7014.77 46.810 162.850 6011.44 6056.24 7108.80 44.640 162.980 6077.08 6121.88 7202.33 41.880 163.850 6145.18 6189.98 7297.06 38.100 163.540 6217.75 6262.55 7391.22 34.620 164.790 6293.57 6338.37 Local Coordinates Northings Eastings (ft) (fi) 731.45 S 1468.62 E 752.99 S 1510.15 E 773.05 S 1551.78 E 793.46 S 1593.13 E 805.35 S 1616.00 E 831.51 S 1665.63 E 852.67 S 1706.80 E 875.33 S 1747.60 E 900.30 S 1788.29 E 925.37 S 1828.94 E 951.62 S 1869.12 E 982.30 S 1909.06 E 1017.49 S 1947.91 E 1057.54 S 1985.63 E 1102.81 S 2020.65 E 1153.68 S 2051.41 E 1210.80 S 2076.61 E 1274.03 S 2097.75 E 1341.15 S 2117.50 E 1411.80 S 2137.09 E 1486.45 S 2157.77E 1560.71 S 2179.51 E 1634.71 S 2202.54 E 1707.00 S 2226.63E 1776.54 $ 2250.33E 1844.05 S 2272.10 E 1908.40 S 2291.88 E 1969.82 S 2310.19 E 2028.24 S 2327.27 E 2081.93 $ 2342.52 E Global Coordinates Northings Eastings (ft) (ft) 6028732.37N 559487.74 E 6028711.15 N 559529.43 E 6028691.42 N 559571.22 E 6028671.34N 559612.72 E 6028659,62 N 559635.68 E 6028633.85 N 559685.52 E 6028613.02 N 559726.85 E 6028590.68 N 559767.83 E 6028566.02 N 559808.71E 6028541.26 N 559849.55 E 6028515.33N 559889.94 E 6028484,97 N 559930.12 E 6028450.08 N 559969.24 E 6028410.32 N 560007.27 E 6028365.33N 560042.64 E 6028314.70 N 560073.80 E 6028257.78 N 560099.45 E 6028194.71 N 560121.07 E 6028127.76 N 560141.35 E 6028057.25 N 560161.49 E 6027982.77 N 560182.75 E 6027908.68 N 560205.07 E 6027834.86 N 560228.68 E 6027762.77 N 560253.33 E 6027693.42 N 560277.57 E 6027626.07 N 560299.87 E 6027561.88 N 560320.15 E 6027500.60 N 560338.93 E 6027442.32 N 560356.47 E 6027388.75 N 560372.14 E Dogleg Rate (°/100fi) 0.345 1.687 0.662 0.812 1.021 0.321 0.494 2.607 0.443 0.491 2.189 3.550 3.190 3.476 4.356 5.336 6.101 4.714 2.121 5.384 2.630 0.861 1.083 2.925 3.056 3.644 2.310 3.019 3.996 3.779 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 1551.36 1595.83 1639.34 1682.87 1707.39 1760.85 1804.80 1849.57 1895,91 1942.29 1989.18 2039.06 2091.39 2146.39 22O3.22 2261.05 2319.45 2379.35 2441.05 2505.15 2572.87 2641.05 2709,96 2778.38 2844.58 2907.98 2967.72 3024.35 3077.97 3126.94 5 September, 2001 - 9:23 Page 3 of 5 DrillQues t 2. 00. 08. 005 Sperry-Sun Drilling Services Survey Report for MPC-24 Your Reh APIEO0292302000 Job No. AKZZ11117, Surveyed: 25 July, 2001 Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) Ct) (ft) Local Coordinates Global Coordinates Northinga Eaatlnga Northinga Eaatlngs (ft) Ct) (~t) (~t) 7484.99 33.190 165.190 6371.39 6416.19 2132.45 S 2356,07 E 6027338.34 N 560386,09 E 7579.09 32.390 165.480 6450,50 6495.30 2181.75 S 2368.97 E 6027289.14 N 560399.37 E 7618.14 31.870 165.490 6483.57 6528.37 2201.85 S 2374.18 E- 6027269.08 N 560404,74 E 7727.42 31.360 166.050 6576.63 6621.43 2257.38 S 2388.26 E 6027213,66 N 560419,25 E 7769.22 31.060 166.630 6612.38 6657.18 2278.43 S 2393.38 E 6027192.66 N 560424.53 E 7867.22 29.640 166.970 6696.94 6741.74 2326.63 S 2404.69 E 6027144.54 N 560436.22 E 7957.66 28.740 167.530 6775.90 6820.70 2369.65 S 2414.43 E 6027101.60 N 560446,29 E 8049.85 27.330 167.170 6857,27 6902.07 2411.93 S 2423,91 E 6027059.39 N 560456,11 E 8143.70 25.380 167.860 6941.36 6986.16 2452.60 S 2432.93 E 6027018.79 N 560465.44 E 8238.59 23.640 166.890 7027.70 7072.50 2491.02 S 2441.52 E 6026980.45 N 560474.33 E 8331.80 21.580 167.100 7113.74 7158.54 2525.93 S 2449.59 E 6026945.60 N 560482.67 E 8406.00 21.580 167.100 7182.74 7227.54 2552.53 S 2455.68 E 6026919.04 N 560488.97 E All data is in Feet (US) unless otherwise statedl Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.259° (16-Jul-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 135.470° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8406.00ft., The Bottom Hole Displacement is 3542.00ft., in the Direction of 136.108° (True). Dogleg Rate (°n00ft) 1.543 0.866 1.332 0.538 1.016 1.460 1.040 1.540 2.103 1.882 2.212 0.000 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 3172.46 3216.65 3234.64 3284.10 3302.69 3344.98 3382.48 3419,27 3454.59 3488.00 3518,55 3541.78 Projected Survey 5 September, 2001 - 9:23 Page 4 of $ DrillQuest 2. 00.08. 005 Sperry-Sun Drilling ServiCes Survey Report for MPC-24 Your Ref: APi500292302000 Job No. AKZE11117, Surveyed: 25 July, 2001 Milne Point Unit Alaska Drilling & Wells Milne Point MPC Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 1929.94 1896.13 92.45 S 260.60 E 8406.00 7227.54 2552.53 S 2455.68 E Comment Tie On Point Projected Survey Survey tool program for MPC-24 From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) Vertical Depth (ft) 0.00 0.00 1965.09 1929.39 1965.09 1929.39 8406.00 7227.54 Survey Tool Description AK-1 BP_HG (MPC-24_Gyro) AK-6 BP_IFR-AK (MPC-24) 5 September, 2001 - 9:23 Page 5 of 5 DrillQuest 2. 00. 08. 005 04-Sep-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPC-24 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD 'MD 8,406.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) Milne Point Unit Alaska Drilling & Wells Milne Point MPC, Slot MPC-24 MPC-24 MWD Job No. AKMM11117, Surveyed: 25 July, 2001 SURVEY REPORT 5 September, 2001 Your Reft API500292302000 Surface Coordinates: 6029452.34 N, 558013.45 E (70° 29' 27.9035" N, Kelly Bushing: 44.80ft above Mean Sea Level 149° 31' 32.6502" W) 0 Ft II.. I, iNG -'S I~1:t~_i C E S A Halliburton Company Survey Ref: svy9931 Sperry-Sun Drilling Services Survey Report for MPC-24 MWD Your Ref: API500292302000 Job No. AKMM11117, Surveyed: 25 July, 2001 Milne Point Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 1929.94 18.700 115.400 1851.33 1896.13 1965.09 19.010 113.890 1884.59 1929.39 2056.56 23.620 117.970 1969.79 2014.59 2150.23 23.910 118.330 2055.51 2100.31 2244.50 26.180 117.940 2140.91 2185.71 2338.80 28.900 117.360 2224.52 2269.32 2432.69 31.620 120.200 2305.61 2350.41 2526.66 31.670 117.170 2385.62 2430.42 2620.92 29.850 116.140 2466.61 2511.41 2715.22 29.620 115.980 2548.50 2593.30 2809.26 29.230 114.820 2630.41 2675.21 2903.06 30.820 115.620 2711.62 2756.42 2997.56 31.110 119.370 2792.66 2837.46 3090.90 31.260 120.270 2872.51 2917.31 3184.70 31.060 115.580 2952.79 2997.59 3278.65 30.740 117.310 3033.40 3078.20 3372.60 30.710 117.750 3114.17 3158.97 3466.19 30.870 116.900 3194.57 3239.37 3561.16 30.710 118.870 3276.15 3320.95 3653.78 30.800 119.450 3355.75 3400.55 3748.69 30.930 118.930 3437.21 3482.01 3842.27 31.060 118.350 3517.43 3562.23 3935.20 31.150 117.250 3597.00 3641.80 4029.04 31.070 118.960 3677.35 3722.15 4122.75 31.050 118.240 3757.62 3802.42 4216.51 30.890 117.750 3838.02 3882.82 4311.15 30.640 118.810 3919.34 3964.14 4404.96 31.090 117.640 3999.86 4044.66 4499.06 31.430 118.360 4080.30 4125.10 4593.75 30.160 118.740 4161.64 4206.44 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 92.45 S 260.60 E 6029361,92 N 558274.76 E 97.19 S 270.92 E 6029357.27 N 558285.12 E 111.83 S 300.74E 6029342.86 N 558315.06 E 129.64 S 334.03 E 6029325.31 N 558348.48 E 148,45 S 369.22 E 6029306.78 N 558383.81 E 168.67 S 407.84E 6029286.86 N 558422.59 E 191.48 S 449,27 E 6029264.37 N 558464.20 E 215.14 S 492.51 E 6029241.05 N 558507.62 E 236.78 S 535.59 E 6029219,75 N 558550,87 E 257.32 S 577.60E 6029199.53 N 558593.04 E 277.14 S 619,34E 6029180.04 N 558634.93 E 297.15 S 661.79 E 6029160.37 N 558677.54 E 319.59 S 704.90E 6029138.26 N 558720.82 E 343.63 S 746.83E 6029114.55 N 558762.94 E 366.34 S 789.68E 6029092.17 N 558805.97 E 387.83 S 832.88 E 6029071.02 N 558849.33 E 410.01S 875.44E 6029049.17 N 558892.06 E 432.00S 918.00E 6029027.51 N 558934.80 E 454.73S 960.97 E 6029005.12 N 558977.94 E 477.81S 1002.33E 6028982.36 N 559019.48 E 501.56 S 1044.84E 6028958.95 N 559062.17 E 524.66 S 1087.13 E 6028936.18 N 559104,64 E 547.04 S 1129.60E 6028914.13 N 559147.28 E 569.88 S 1172.36 E 6028891.62 N 559190.22 E 593.03 S 1214.81 E 6028868.81 N 559232.85 E 615.67 S 1257.41 E 6028846.50 N 559275.63 E 638.61S 1300.04 E 6028823.90N 559318.43 E 661.36 S 1342.45 E 6028801.47 N 559361.01 E 684.29 S 1385.56 E 6028778.88N 559404.31E 707.46 S 1428.14 E 6028756.05 N 559447.07 E Dogleg Rate (°/100fi) 1.645 5.291 0.346 2.414 2.898 3.273 1.692 2.010 O.258 0.734 1.748 2.064 0.524 2.595 1.005 0.241 0.495 1.075 0.335 0.313 0.348 0.619 0.945 0.397 0.319 0.631 0.800 0.537 1.357 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 248.66 Tie On Point 259.28 MWD Magnetic 290.62 326.66 364.75 406.25 451.57 498,76 544.39 588.51 631.90 675.93 722.16 768.70 814.95 860.56 906.22 951.75 998.08 1043.54 1090.28 1136,40 1182.14 1228,42 1274.68 1320.70 1366.95 1412.91 1459.49 1505.86 5 September, 2001 - 9:21 Page 2 of 5 DrillQuest 2. 00.08. 005 Sperry-Sun Drilling Services Survey Report for MPC-24 MWD Your Ref: API500292302000 Job No. AKMM11117, Surveyed: 25 July, 2001 Milne Point Unit Measured Depth incl. Sub-Sea Depth (ft) Vertical Depth (ft) 4687.46 30.000 119.010 4242.73 4287.53 4781.56 29.640 117.760 4324.37 4369.17 4875.90 29.030 114.350 4406.62 4451.42 4970.32 29.430 116.170 4489.02 4533.82 5022.81 29.400 117.130 4534.74 4579.54 5136.59 29.690 117.290 4633.73 4678.53 5230.45 29.410 116.530 4715.38 4760.18 5323.99 30.490 120.930 4796.43 4841.23 5417.77 30.720 121.740 4877.15 4921.95 5511.82 30.310 121.370 4958.17 5002.97 5605.39 31.440 124.740 5038.49 5083.29 5699.68 33.190 130.140 5118.19 5162.99 5793.05 35.160 134.110 5195.44 5240.24 5887.16 36.450 139.420 5271.78 5316.58 5981.41 38.430 145.150 5346.64 5391.44 6075.09 40.480 152.380 5419.01 5463.81 6168.78 43.270 159.780 5488.80 5533.60 6262.84 47.050 163.290 5555.13 5599.93 6357.02 48.910 163.940 5618.17 5662.97 6450.85 53.920 164.840 5676.67 5721.47 6545.28 56.320 164.640 5730.67 5775.47 6638.42 56.030 164.200 5782.51 5827.31 6732.18 55.490 162.400 5835.27 5880.07 6826.11 52.940 160.870 5890.19 5934.99 6919.97 50.100 161.200 5948.59 5993.39 7014.77 46.810 162.600 6011.46 6056.26 7108.80 44.640 162.940 6077.09 6121.89 7202.33 41.880 163.870 6145.20 6190.00 7297.06 38.100 163.680 6217.77 6262.57 7391.22 34.620 164.710 6293.58 6338.38 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 730.14 S 1469.27 E 6028733.69 N 559488.37 E 752.38 S 1510.44E 6028711.76 N 559529.71 E 772.69 S 1551.94 E 6028691.78 N 559571.37 E 792.36 S 1593.63E 6028672.43 N 559613.21E 803.93 S 1616.67 E 6028661.05 N 559636.34E 829.58 S 1666.56 E 6028635.79N 559686.44 E 850.53 S 1707.84E 6028615.16 N 559727.87 E 872.99 S 1748.75E 6028593.02N 559768.96 E 897.82 S 1789.53 E 6028568.51 N 559809.93 E 922.81 S 1830.22 E 6028543.83 N 559850.82 E 949.01 S 1870.44E 6028517.95 N 559891.24 E 979.67 S 1910.39 E 6028487.60 N 559931.43 E 1014.87 S 1949.24 E 6028452.71 N 559970.55 E 1054.97 $ 1986.89 E 6028412.90 N 560008.51 E 1100.29 $ 2021.86 E 6028367.85N 560043.83E 1151.16 S 2052.61 E 6028317.23 N 560074.98 E 1208.28 S 2077.83E 6028260.30 N 560100.64E 1271.54S 2098.88 E 6028197.22 N 560122.18 E 1338.66 S 2118.61 E 6028130.25 N 560142.44 E 1409.28 S 2138.32 E 6028059.78N 560162.70 E 1484.01S 2158.71E 6027985.22 N 560183.67 E 1558.54 S 2179.49 E 6027910.85 N 560205.03 E 1632.78 S 2201.76 E 6027836.79 N 560227.88 E 1705.09 S 2225.75E 6027764.67 N 560252.43 E 1774.57 S 2249.63E 6027695.38 N 560276.85 E 1841.99 S 2271.69 E 6027628.13 N 560299.44 E 1906.29 S 2291.63E 6027563.99 N 560319.88 E 1967.71S 2309.95 E 6027502.72N 560338.68 E 2026.15 S 2326.95 E 6027444.41 N 560356.14 E 2079.85 S 2342.17 E 6027390.83 N 560371.78 E Dogleg Rate (°/100ft) 0.224 0.763 1.885 1.032 0.900 0.264 0.498 2.616 0.504 0.480 2.207 3.579 3.186 3.573 4.249 5.367 6.051 4.810 2.040 5.392 2.547 0.501 1.688 3.019 3.038 3.642 2.322 3.029 3.992 3.752 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 1550.88 1595.60 1639.18 1682.45 1706.85 1760,13 1804,01 1848.71 1895.01 1941.36 1988.24 2038,12 2090.45 2145.45 2202.27 2260.10 2318.51 2378.36 2440.05 2504.22 2571.79 2639.50 2708.03 2776,41 2842.69 2906.22 2966.04 3022.67 3076.26 3125.21 5 September, 2001 - 9:21 Page 3 of $ DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPC-24 MWD Your Ref: AP!500292302000 Job No. AKMM11117, Surveyed: 25 July, 2001 Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northlngs Eastings Northings Eastlngs (ft) (ft) (ft) (ft) 7484.99 33.190 165.000 6371.41 6416.21 2130.34 S 2355.84 E 6027340.45 N 560385.84 E 7579.09 32.390 164.840 6450.51 6495.31 2179.54 S 2369.10 E 6027291.35 N 560399.48 E 7618.14 31.870 164.810 6483.58 6528.38 2199.59 S 2374.53 E 6027271.35 N 560405.07 E 7727.42 31.360 165.810 6576.64 6621.44 2255.00 S 2389.06 E 6027216.05 N 560420.03 E 7769.22 31.060 166.140 6612.39 6657.19 2276.01 $ 2394.31 E 6027195.08 N 560425.45 E 7867.22 29.640 168.000 6696.96 6741.76 2324.26 S 2405.41 E 6027146.92 N 560436.92 E 7957.66 28.740 168.530 6775.92 6820.72 2367.45 S 2414.38 E 6027103.80 N 560446.23 E 8000.76 28.150 167.460 6813.81 6858.61 2387.53 S 2418.65 E 6027083.76 N 560450.65 E 8049.85 27.330 167.370 6857.26 6902.06 2409.83 S 2423.63 E 6027061.50 N 560455.81 E 8143.70 25.380 167.680 6941.35 6986.15 2450.50 S 2432.63 E 6027020.89 N 560465.13 E 8238.59 23.640 166.900 7027.69 7072.49 2488.90 S 2441.28 E 6026982.56 N 560474.08 E 8331.80 21.580 167.030 7113.73 7158.53 2523.81 $ 2449.37 E 6026947.71 N 560482.43 E 8406.00 21.580 167.030 7182.73 7227.53 2550.41 S 2455.49 E 6026921.17 N 560488.77 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.218° (31-Aug-01) The Dogleg Severity is in Degrees per 100 feet (US). Vedical Section is from Well and calculated along an Azimuth of 135.470° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8406,00ft,, The Bottom Hole Displacement is 3540.34ft., in the Direction of 136.086° (True). Dogleg Rate (°/lOOfl) 1.535 0.855 1.332 0.669 0.826 1.737 1.035 1.809 1.673 2.083 1.865 2.211 0.000 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 3170.79 3215.17 3233.27 3282.96 3301.62 3343.80 3380.88 3398.19 3417.57 3452.89 3486.33 3516.88 3540.14 Projected Survey 5 September, 2001 - 9:21 Page 4 of $ DrillQues t 2. 00. 08. 005 Sperry-Sun Drilling Services Survey Report for MPC-24 MWD Your Ref: API500292302000 Job No. AKMM11117, Surveyed: 25 July, 2001 Milne Point Unit Alaska Drilling & Wells Milne Point MPC Comments Measured Station Coordinates Depth TVD Northings Eastings (fi) (ft) (ft) (ft) 1929.94 1896.13 92.45 S 260.60 E 8406.00 7227.53 2550.41 S 2455.49 E Comment Tie On Point Projected Survey Survey tool program for MPC-24 MWD From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) Vertical Depth (fi) 0.00 0.00 1965.09 1929.39 1965.09 1929.39 8406.00 7227.53 Survey Tool Description AK-1 BP_HG (MPC-24_Gyro) MWD Magnetic (MPC-24 MWD) 5 September, 2001 - 9:21 Page $ of $ DrillQuest 2.00. 08. 005 7/31/2001 Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 1335 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 9950'1 Endicott, Niakuk,Milne Point Well Job # Log Description Date BL Sepia Color CD NK-07A ~--O J - ~)~'~ 21341 MGR (PDC) 04126101 5-02/SAG 10 /~/-_//~ PSP-LDL 07123101 '1 1 MPC-24 '~-~OI - O ~ MDT 07125101 I 1 C~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: RECEIVED BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Schlumberger GeoQuest AUG 0,~ 2001 3940 Arctic Blvd Anchorage, AK 99503 ~ 0~1 & (~,~ Co~$. CofTlJTlJ~Ofl A~N: Sherrie ~~ Received [Fwd: Milne Pt. Unit C-24 - Divcrter Waiver Request] Subject: [Fwd: Milne Pt. Unit C-24 - Diverter Waiver Request] Date: Tue, 03 Jul 2001 14:26:44 -0800 From: Julie Heusser <julie_heusser~admin.state.ak.us> To: John D Hartz <jack_hartz~admin.state.ak.us> Hi Jack, Here's the scoop on the diverter at MPU C Pad. The operator needs to put their request in writing, however, it sounds as if this would be a smart one to approve. Thanks Julie Subject: Re: Milne Pt. Unit C-24 - Diverter Waiver Request Date: Mon, 02 Jul 2001 19:28:05 -0800 From: John Crisp <john_crisp~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, AOGCC To: Julie Heusser <julie__heusser~admin.state.ak.us> CC: Robert Crandall <Bob_Crandall@admin.state.ak.us>, Jack Hartz <jack_hartz~admin.state.ak.us> Howdy, I witnessed a BOP test on MPU C-41 6-09-01 Rig 22E. They were N/D Diverter when I arrived on location. The 10" Div. vent line was out the back of the Rig under flow lines & cable trays that had Hi Voltage electric cables in the trays. The line looked to be about 70' long w/ a 90 deg. turn @ the end. The Div. line didn't seem to be anchored @ the end. I did not witness the Div. test on this well. I expressed my concern for this Diverter line to Operator Rep. Duncan Ferguson & Contractor Rep. Larry Wurdeman. Duncan & Larry expressed concern for their next well because it would be 12 1/4" hole. They asked about the possibility of obtaining a waiver to drill the 12 1/4" hole w/ a 10" Div. vent line. Untill a major modification could be made to 22E they would have to run the line the same way ( thru flow lines & cable trays). I told Duncan that it was possible to obtain a Div. variance in well by well cases. I reminded Duncan that the Div. was for safe evacuation of the Rig in case of emergencies. Concern was expressed for Rig evacuation Procedures & Standing orders for evacuation. The Driller has an emergency power shut down button on his console. If the well was flowing out of control it would probably cause less damage if it flowed thru the Rig than if it was flowing thru a Diverter line that could damage flow lines & electric cables. Again, this is dependent on Safe evacuation & total power shut down on the Rig. I did not tell the Operator Rep. he should request a Diverter waiver, I just told him his options. Lou & I both agree, in some cases a bad Diverter line is more hazardous than no line at all. Sorry for the long reply to your note. Give me a call if you have questions. JC. Julie Heusser wrote: Hello Ail, I'm wracking my brain here about some problem with diverter waivers at MPU C Pad - it may simply be a piping issue. However, if the slope PI's concur, then I'll buy off on it too. Thanks Julie Robert Crandall wrote: I of 2 7/3/2001 2:42 PM [Fwd: Milne Pt. Unit C-24 - Divertcr Waiver Request] > > Jack & Julie: > > > C-pad has had a number of kicks in the intermediate hole. Julie remember > > when a crew from BP came over to talk to us about that? The surface > > hole has not had any incidence related to shallow hazards as far as I > > know. If the analysis conducted by BP states this, I recommend approval. > > RPC > > > Jack Hartz wrote: > > > >>>fy/ > > > > > BPX will be dropping off a request for diverter waiver for C-24 today. > > > They expect to spud on or about Friday. The reasons cited over the > > > phone were: > > > 1. Pad congestion in the area of C-24. > > > 2. There have been no Shallow hazards encountered in drilling off of C > > > Pad to date. > > > > > Usually the above a good reasons. Do we have a general email address > > > for the NS Inspectors to forward this so they can be aware and express > > > any opinions they may have? > > > > > do either of you have any opinions? > > > > > > jack 2 of 2 7/3/2001 2:42 PM BP Exploration (Alaska)Inc PO Box 196612 Anchorage, AK 99519-6612 Tom Maunder Petroleum Engineer AOGCC o/-o / RECEIVED 333 W. 7" Avenue Suite 100 ~ JUL u Anchorage, AK 99501-3539 ~, AJaska Oil & Gas Co~s. Commissio~ Re' Milne Point Unit MPC-24 (Diverter) .- · BP Exploration (Alaska)Inc. ~- ...._... ......... Permit No. 201-094...~-.------~-~ - ' Surface Location: 1171' NSL, 2446' WEL, SEC. 10, T13N, R10E, UM Btmhole Location: 3945' NSL, 5264' WEL, SEC. 14,T13N, R10E, UM Dear Mr. Maunder: In reference to the above mention well, BP would like a wavier to drill this well without a diverter system. The proposed surface hole would be drilled just below the Schrader bluff "OB" sand without a diverter. A full sting 9-5/8" casing would be set and BOP's nipples up prior to drilling out of the surface casing. The Schrader Bluff sands are wet in the direct offset wells. Gas hydrates and abnormal pressures are not anticipated. The Nabors 22E drilling rig is currently on the MPU "C" pad drilling the C-41 Schrader Bluff multi-lateral well and will be moving to spud the C-24 well on or about Thursday, July 5, 2001. Your prompt attention to the request is appreciated. Please call Steve Campbell (564-4401) or Pat Archey (564-5803) if you have any questions. Sincerely, Ste¥o Campbell Operations Ddlling Fngineer ALASKA OIL AND GAS CONSERYA~ION COP~SSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Steve Shultz Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Milne Point Unit MPC-24 BP Exploration (Alaska) Inc. Permit No: 201-094 Sur Loc: 1171' NSL, 2446' WEL, SEC. 10, T13N, R10E, UM Btmhole Loc. 3945' NSL, 5264' WEL, SEC. 14, T13N, R10E, UM Dear Mr.'Shultz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application Milne Point Unit MPC-24. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Cammy Taylor Chair BY ORDER OF THE COMMISSION DATED this ~ day of June, 2001 jjc/Enclosures CC: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~;"- ' ALASKA'~ .,.. AND GAS CONSERVATION coMMt,..,¢ION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Planned KBE = 46.10' Maine Point Unit / Kuparuk 3. Address 6. Property Designation River Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL047437 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1171' NSL, 2446' WEL, SEC. 10, T13N, R10E, UM Maine Point Unit At top of productive interval 8. Well Number 5250' NSL, 325' WEL, SEC. 15, T13N, R10E, UM MPC-24 Number 2S100302630-277 At total depth 9. Approximate spud date 3945' NSL, 5264' WEL, SEC. 14, T13N, R10E, UM 06/04/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL025516, 14' MDI No Close Approach 2560 8395' MD/7226' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' MD Maximum Hole Angle 53.5 o Maximum surface 3885 psig, At total depth (TVD) 6573'/4542 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 92# H-40 Welded 80' 30' 30' 113' 113' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 5045' 30' 30' 5045' 4596' 891 sx AS Lite, 406 sx Class 'G' 8-1/2" 7" 26# L-80 BTC 7703' 30' 30' 7703' 6595' 179 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 BTC 845' 7550' 6465' 8395' 7225' 117 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface IntermediateRECEIVED Production Liner MAY 1 ? Z001 Alaska 0ti & Gas Cons. Commission Perforation depth: measured Anchorage true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Franks, 56~-4468 Prepared By Name/Number: Sondra Stewman, 564-4750 21. I hereby certify that the f,d'/9~oing is t~,~n~rrect to the best of my knowledge Signed SteveShultz ~-~.4,4.,~ Title Senior Drilling Engineer Date ~"//~~... ; .:".;"'.'...::.'.'::'..:. ,': "'.':;';' "?'(~ '.'. :.i:':::: ' ,!.~;'[':..' "':'~;;i'"..";".:"i! ''';:;'cOmmissiOn Us~e. O,1¥"..:~ :" :.";' '"": ' "." .''!' · '. ..... .'": /.':':: '. "." ":" :'" · Permit Number I APl Number I fApprpya, D. ate I See cover letter ~O\-~)~--~L\ 50- (~3'~--~"- "~'~(~'~-~...~ ~,~_! (._~ [,~',) I for other requirements Conditions of Approval: Samples Required [] Yes J;~lq~lo Mud Log Hequ~reu [] Yes [~o Hydrogen Sulfide Measures ~es [] No Directional Survey Required ]~Yes~]~o Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K [] 3.5K psi forCTU u,, tb ¥ grig,ha, ~igned'By by order of _Approved By Cammy 0echsli Commissioner the commission Date Form 10-401 Rev. 12-01-85 'RIGINAL n Friplicate MPC-24 Drillin~l Permit 1. Well Plan Summary IWellName: IMPC-24 I I Type of Well (producer or injector): I Grassroots Producer Surface Location: 1171' FSL, (4108' FNL), 2446' FEL (2833' FWL), SEC. 10, T13N, R10E X = 558013 Y = 6029452 C~24 Target start: :: 5250; FSL, (29, FNL), 325, FEL (4953, FWL), SEC. 15,:T13N, R10E X = 560145 Y = 6028268 Z = 5600' TVDss C-24 Intermediate Target: 4199' FSL, (1079' FNL), 55' FEL (5223' FWL), SEC. 15, T13N, R10E X = 560425 Y = 6027220 Z = 6570' TVDss C-24 Intermediate Target: 4128' FSL, (1150' FNL), 36' FEL (5242' FWL), SEC. 15, T13N, R10E X = 560445 Y = 6027149 Z = 6650' TVDss C-24 Target End: 3994' FSL, (1285' FNL), 5278' FEL (1' FWL), SEC. 14, T13N, R10E X = 560484 Y = 6027015 Z = 7035' TVDss C-24 Target (Bottom Hole Location): 3945' FSL, (1334' FNL), 5264' FEL (14' FWL), SEC. 14, T13N, R10E X - 560498 Y = 6026966 Z = 7175' TVDss ~ Nabors22E I Estimated Start Date: I UDrkb Well Desitin (conventional, slim hole, etc.): I Ultraslimhole Grassroots Producer Well Scope: I Drill and Complete a producing well in the Kuparuk sands. I June 4, 2001 I I Operatin~l days to complete: ! TVDrkb(TD) ~7226'~ I Max. Inc. 53~~.5° ~ Version #1,5/7/2001 1 Current Well Information MPC-24 Drillin~l Permit 2.1 2.2 General Well Name: MPC-24 APl Number: Well Type: Current Status: BHP: BHT: MPC-24 Development - Kuparuk Producer Conductor Set 4542 psi @ 6573' TVDss Kalubik silts. Abnormal pressure gradient 170°F @ 7000' TVDss Estimated (SOR)---- Current Mechanical Condition MPC-24: Nabors 22E: Conductor: Cellar Box above MSL = 16.2' KB / MSL = 45.3' 20", 92 Ib/ft, H-40 Welded set at 113' MD 3. Drillin_cl Hazards and Contingencies MPC-24 Drilling Permit 3.1. Well Control MANDATORY WELL CONTROL DRILLS: Drill Type Frequency Comments D1 Tripping (1) per week, per crew Conducted only inside casing. D2 Drilling (1) per week, per crew Either in cased or open hole. DO NOT shut-in well in open hole. D3 Diverter N/A N/A D4 Accumulator Prior to spud or RWO Approx. every 30 days, thereafter at convenient times. D5 Well Kill Prior to drill out, Prior to drill out the intermediate and production strings. Never per crew carry out this drill when open hole sections are exposed. 3.2. Kick tolerance 3.2.1. The 9-5/8" casing will be cemented to surface. The top of the 15.8 lb/gal tail cement slurry is planned to be 4114' MD. 3.2.2. The Kick Tolerance for the 9-5/8" surface casing, based on the 9.0 ppg expected pore pressure, is 65.9 bbls with an 11.5 ppg FIT. 3.2.3. The Kick tolerance for the 7" intermediate casing, based on the maximum 13.3 ppg pore pressure, is INFINITE with a 14.8 ppg FIT. 3.3. Lost Circulation 3.3.1. Lost circulation has been encountered in the C Pad wells attributable to the "Breathing" in the Milne Point field while cementing Iongstring casing jobs. No lost circulation is expected due to top setting the Kuparuk interval. 3.3.2. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. 3.4. Expected Pressures 3.4.1. The Pad Data Sheet documents numerous instances of ..over pressure. Abnormal pressures are present both in and above the Ku~aruk zone in the heavily develope~j'portion of the C pad area and have required mud weights as high as 13.8 ppg. These high-pressure intervals are a result of water and gas injection in the greater 'C' pad area. The C-24 well is designed with the anticipation of encountering abnormally pressured formations below the base of the HRZ. Based on the offset well information, the anticipated mud weight should be 10.5 ppg and as high as 13.8 ppg. A full string of 7" casing will be run just below the base of the HRZ formation prior to drilling into potentially pressured Kuparuk sands. 3.5. Pad Data Sheet 3.5.1. Please Read the C-Pad Data Sheet thoroughly. 3.6. Breathing 3.6.1. Breathing/lost circulation is well documented at Milne Point between the Schrader Bluff and the 3 MPC-24 Drillin~l Permit HRZ when mud weights reach 11.5 ppg. If well bore breathing/lost circulation occurs on C-24, the Alaska Drilling and Wells RP "Well Bore Breathing" will be followed. As stated in that RP, it is ADW policy that any flow from the well will be treated as a well control problem until a definitive well bore breathing diagnosis is made. This is especially important on C-24 due to the history of abnormal pressures at 'C' pad. 3.7. Hydrocarbons 3.7.1. Hydrocarbons will be encountered in the Kuparuk intervals. 3.8. Faults 3.8.1. No Faults should be crossed along the designed well profile, however should the base of the HRZ come in 80' Iow, then there is the possibility that we might have crossed a major NW-SE fault. At this point we will need to stop drilling and evaluate how to get back into the targeted upthrown target. 3.11 Hydrogen Sulfide 3.11.1. MPC Pad is not designated as an H2S Pad. Below is a summary of the most recent H2S readings: Well E- Well Type H2S Status Date taken 1 KUP Prod 4.8 May 2000 3 KUP Prod <2.00 Feb 2000 4 KUP Prod 6.30 Apr 2000 5 KUP Prod 6.8 May 2000 6 WAG Shut In Feb 2000 7 KUP Prod 5.7 May 2000 9 KUP Prod <2.00 Feb 2000 14 KUP Prod 19.8 May 2000 15 WAG <2.00 Apr 2000 19 WAG Shut In Feb 2000 22 KUP Prod 3.20 Apr 2000 25 WAG Shut In Feb 2000 4. Drillin_cl Program Overview MPC-24 Drillin~l Permit 4.1. Surface and Anti-Collision Issues Surface Shut-in Wells: No wells need to be shut-in for the rig move on and off MPC-24 Close Approach Wells: There are no close approach wells. Close Tolerance Wells: There are close tolerance wells in drilling the surface hole. The closest well is listed below. Well Name Current Production Precautions Status Priority C-25/C-25A Prod N/A Risk assessment to be conducted. Gyro to be run in the surface casin~l. Follow the travelin~l cylinder closely. 4.2. Well Control- Nabors 22E BOP stack Expected BHP Max Exp Surface Pressure BOPE Rating Planned BOPE Test Pres. 4542 psi @ 6573' TVD 3885 psi 13 5/8" 5M *Rams & Valves: 4000 psi/250 psi (estimated) /0.1 psi/ft ~las ~lradient) Annular: 2500 psi/250 psi 4.3. Mud Program 12-1/4" Surface Hole Mud Properties: Density(PPg) IFunnelvisc I YP 8.6 - 9.6 100 - 150 25 - 60 8-1/2" Intermediate Hole Mud Properties: Density(PPg) IFunnelvisc I YP 9.5 - 10.5 40 - 52 12 - 20 6-1/8" Production Hole Mud Properties: Density (pp~l) I Funnel vise[ YP 11 - 13.8 35 - 45 12 - 20 HTHP N/A HTHP 10-12 HTHP 10-12 Spud - LSND Freshwater Mud pH I API Filtrate LG Solids 9.0-9.5I <6 <6.5 LSND Freshwater Mud pH I API Filtrate LG Solids 8.5-9.5I <6 <6.5 LSND Freshwater Mud pH I APl Filtrate LG Solids 8,5-9.5I <6 <6.5 Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1R. MPC-24 Drillin~l Permit 4.4. Formation Markers TVDss TVDrkb Formation Tops MDrkb(ft) (ft) (ft) Pore Pressure (Psi) Estimated EMW(ppg) BPRF 1814 1740 1786 SB F2-NA 4614 4180 4226 1881 8.7 TSBD-OA 4784 4325 4372 1946 8.7 TSBB-OB 4859 4390 4444 SBA5 (base OB) 4882 4410 4467 THRZ / TUDZ 7518 6392 6438 9.0 BHRZ 7667 6519 6565 . KLGM 7731 6573 6619 4542 max. 10.5-13.3 TKUD 7819 6648 6694 TKUC 7943 6758 6804 3250 9.3 TKA3 8132 6932 6978 TKA2 8157 6956 7002 TMLV 8241 7035 7081 9.0 TD 7170 4.5. Casing/Tubing Program Hole Size Csg / Wt/Ft Grade Conn Length Top Bottom Tb~ O.D. MD / TVDrkb MD / TVDrkb 30" 20" 92# H-40 Welded 80' 30' / 30' 113' / 113' 12-1/4" 9-5/8" 40# L-80 BTC 5045' 30' / 30' 5045' / 4596' 8-1/2" 7" 26# L-80 BTC 7703' 30' / 30' 7703' / 6595' 6-1/8" 4-1/2" 12.6# L-80 BTC 845' 7550'/6465' 8395' / 7225' Tubin~l 3-1/2" 9.3# L-80 EUE +/- 7550' 30' / 30' 7550 / 6465' 4.6. Cement Calculations Casin9 Size I 9-5/8" 40 Ib/ft L-80 BTC-M Basis 250% excess over gauge hole in permafrost interval, 30% excess over gauge hole below permafrost A TAM Port Collar will be Total Cement Volume: )laced at 1000' MD as a contin~lenc¥ for cement not displacing! to surface in one sta~le Wash 50 bbl of Chemical Wash at 8..32 ppg Spacer 75 bbl of MUDPUSH Spacer weighted to 10.20 ppg Lead 521 bbl 10.7 lb/gal AS Lite - 691 sacks Tail Temp BHST = 80° F from SOR, BHCT 70° Casing Size I 7" 26 Ib/ft L-80 BTC-M BasisI 30% excess Total Cement Volume: Wash 20 bbl of Newtonian Chemical Wash (CW100) weighted to 8.32 ppg Spacer Tail Temp 40 bbl of MUDPUSH Spacer weighted to 12 ppg BHST = 170° F from SOR, BHCT 130° F estimated MPC-24 Drillin~l Permit Casin~l Size I 4-1/2" 12.6 Ib/ft L-80 BTC-M BasisI 30% excess Total Cement Volume: Wash Spacer Tail 20 bbl of Newtonian Chemical Wash (CW100) weighted to 8.32 ppg 40 bbl of MUDPUSH Spacer weighted to 14.5 ppg 25 bbl 15.8 lb/gal GASBLOK slurry -117 sacks Temp BHST = 170° F from SOR, BHCT 130° F estimated 4.7. Survey and Logging Program 12 1/4" Hole Section: Open Hole: 8 1/2" Hole Section- Open Hole: 6-1/8" Hole Section: Open Hole: Cased Hole: Dir / GR - Gyro as required Dir / ABGR / Res / PWD At bit GR is extremely important to mitigate the chances of hitting an over pressured formation. Dir / GR / Res / PWD / Neutron / Dens RFT - 30 pressure points (contingent on hole conditions and Iow mud weight) CBL MPC-24 Drillin~l Permit MPC-24 Operations Summary 5.1. Pre-Rig Operations 1. Grade and level pad as needed. 5.2. Procedure 1. MIRU, NU diverter on 20" conductor, PU 5" drill pipe 2. Drill 12 ¼" surface hole as per directional plan. Maximum tangent angle 30.73° 3. Condition mud and spot casing running lube pill prior to 9 5/8" casing run. POOH 4. Run and cement 9 5/8" casing from TD to surface. TAM Port Collar as contingency should cement not reach the surface. 5. ND Diverter 6. Install FMC 11" 5m wellhead 7. N/U and test 13 %" 5m BOP 8. Drill 8 Y2" intermediate hole as per directional plan. Maximum angle 50.85° 9. Run and cement 7" casing from 7700' to 6700' MD, 10. Pick up 3 Y2" drill pipe and drill 6 1/8" production hole as per directional plan. Maximum angle 19.3° 11. RIH with RFT for 30 samples should hole conditions allow. 12. Run and cement 4 1/~,, liner with 150' overlap. 13. Run 3 1/~,, frac completion 14. Freeze protect. ~ ~'(~" 15. ND BOP 16. RDMO 5.3. Post Rig Work 1. MIRU E-Line 2. Run CBL 3. Perforate Kuparuk interval sands 4. RD E-line 5. Perform fracture treatment on zones. 6. MIRU workover rig 7. Run 2 7/8" ESP completion 8. Freeze protect tubing and annulus 9. RDMO Milne Point C-24: Proposed Completion TREE: 3-1/8" - 5M Cameron WELLHEAD: 11"-5M Gen 5A FMC Tubing Hanger: 7-1/16 x 3-1/2 Tubing Head: 11 x 7-1/16 Adapter: 7-1/165M x 3-1/85M 20", 91.1 #Iff, H-40 @ 113'MD (113' TVD) Cellar Elevation = +16.2' RKB-MSL = +45.3' MW = 9.5 ppg 9-5/8", 40 #Iff, L-80, BTC @ +/- 5045' MD ( 4596' TVD) 3-1/2" 9.3# L-80, EUE Sliding Sleeve for Jet Pump completion 7" x 3-1/2" Production Packer above Liner Top TD @ +/- 7700' MD ( 6600' TVD) - HRZ MW = 9.8 ppg TD @ +/- 8395' MD ( 7225' TVD) - 150' below Miluveach MW = 13.8 ppg 7" x 4-1/2" Liner Hanger and Packer @ 7550' MD 7", 26 #Iff, L-80, BTC-Mod 4-1/2", 12.6 #/fi, L-80, BTC-Mod Date 5-7-01 Rev By Comments JDF Proposed Completion WP Milne Point WELL: C-24 APl NO: 50-029-????? BP Alaska Drilling & Wells Milne Point Unit bli~ne Point I~IPC Alaska Drilling & Wells IVIPC-24 WP02 Well: MPC-24 WP02 Horizontal Coordinates: Ref, Global COOrdinates: 6029452.34 N, 558013.45 E Ref. Structure Reference : 210491 N 2817 W i Ref, Geographical Coordinates: 70° 29' 27 7850" N, 149" 3t' 32.6858" W 159 ~0'~ Nodh R~ere~ce: Tr~ Nodh Z Begin 9 5~8" Casing 504487' MD 4596 ~0' TVD Begin Oir @ 5 O0°/100[t: 6894 49It MD, 5962 12ff TVD End Dir, Stad SCl @ 32OOO°: 7331 458MD,6280. I 5ft~VD ~ -2400 7" Casing 7702.8@ MO Tot@ Depth: 8394 531t MD,7225@3ft ~¥D "¢' 7225.53' TVD 3600 0 Scale: linch = 600fl ADW 7" Casing 1200 1 00 2400 Eastings Reference is True North Proposal Data for MPC-24 Wp2 0 1200 2400 Vertical Section Milne Point MPC ~Pm-I~r~-Sl..~. ] Milne Point Unit ="--~c-~-~ A~~ IAlaska Drilling & Wells M PC-24 WP02 MPC-24 Wp2 Formations Measured Vertical Sub-Sea Depth Depth Depth Dip Dip Dir. (ft) (ft) (fi) (Deg) (Deg) 1813.70 1786. 4614.43 4226. 4928.54 4496. 7517.70 6438. 7667.46 6565. 7731.14 6619. 7818.95 6694 7943.35 6804 8131.62 6978 8157.12 7002 8241.06 7081 8389.82 7221 Formation Name 10 1740.00 0.000 0.447 10 4180.00 0.000 0.447 10 4450.00 0.000 0.447 10 6392.00 0.000 0.447 10 6519.00 0.000 0.447 10 6573.00 0.000 0.447 10 6648.00 0.000 0.447 10 6758.00 0.000 0.447 10 6932.00 0.000 0.447 10 6956.00 0.000 0.447 10 7035.00 0.000 0.447 10 7175.00 0.000 0.447 Base Permafrost SBF1-NB TSBB-OB THRZ / TUDZ BHRZ KLGM TKUD TKUC TKA3 TKA2 TMLV OWC Draft Copy Single Well Target Data for MPC-24 WP02 Measurement Units: ft Coordinate Target Point TVD TVD Northings Eastings Northings Eastings Target Name Type ss ASP Y ASP X Shape MPC-24 Target Entry Point 7084.36 7038.26 6027014.72 N 560484.48 E 2456.82 S 2451.94 E Polygon Boundary PointA 7084.36 7038.26 6026990.00N 560070.00 E 2478.31S 2037.28 E B 7084.36 7038.26 6026840.00N 560770.00 E 2633.77 S 2736.08 E C 7084.36 7038.26 6027040.00N 560795.00 E 2433.97 S 2762.64 E D 7084.36 7038.26 6027256.00 N 560082.00 E 2212.41S 2051.35 E Sperf'-Sun Drilling Se .ices Proposal Data - Plan · MPC-24- MPC-24 Wp2 Draft Copy ;'""'-~ ...... '~'125.86; ';.~.5,,~6' 10.000 105.000~'~,22/ .>, :/~;-.~1' ' ' 7.0.7.$I 64.47 E .................. ": ' ""~ '~ ~; ......... I .... ~~:'";'~' 5 1746.69. 620~3 19.000 115.050 .'1722'~7;4{:"-';.'."':~!52~ .63.93S; 208.4tE ..................... -?~. ,_~ ................. ~,.~!. ~-..., .;...,_~ ,.:.,, ,.~..: =~;. · .... :.,. , ~.~- 6 ' 1987.04' . 240~35 19.000 115.050f ..1~~i'!,'? .227.,~1,:>'i::<'9.~;07'S?., 279~30E ..'-'"':+ ...... ~o~.o~C~ ~.ooo'-~ ~:o~o~~:~....,~.]<....:::..',:t~.:s.'i,.:~-~ !.:--~-:-;.- ~,~,z~,i::::~-~: -:,o'.~:,o ..... :,':i~,-:~o-~'~!t~.i~~] ;~~; !....:.~1.:.0.,....: . 6364..341:.:::::,~1_5~_~J . 53.850...!64'3._90. ],ii'~~f :~~; ~I.,~.,+....E:~ "1'1'".' 6894.491'¥.'"530!~] 53.850 164.39078~17'ii.'.!':"::',3.~2;:7."'4~1 ?i<.~;2:3~.'~ '.225~iE. '..~...-:~.......~ ........................... '.~-..~.~,! .............................................. ~..,i,~;.~-. ~i'~i+~.,~ ' ~.;~,~.~.~.~.,."-:.,,..c. . .~:... ?~.~..~'...?..~:~] ~,.ooo .,~.~o ;.'=~~;?,..~;~. ~:'~'.'s:.. · '13: ' 7761.45' ~'': ........ ~, · ..... ,;..,:....-,e.':...~....~=+..~;~], .................. 32.000 164 390' ,6~:,~;' ', 3~'~'~'"~'~: "?'"~="'; ':' '~ .';~;'~:t~'~= == ;=';~2~66~66..S,.~:~":"?-':': ~'~';' '?H~''.2898:a~.':E''~:'''':~'~:''~ .... "';' ':"" ""r:"1"5':: ...... 8244.53 .~.':.'".l'~;l'='='~;'r"":""":"':"~'~"":"'; ............................. 19.760: 164.390r..'r'::""'m='":~-':~~~.;P~['~';~'~'., ~;~.~';,~.~n'l?~ .rD.r,,?~,'.',r~.",-,.~?,',.~,?*'.~2~;~;.S "~":~'"'"~"" ?*';; :'='[c"~: i, ~.~'.;~ ;~; '?: "':; ','. '. ...... ~,: ~.'~r"/"~r":.'~.'.'~?;"~ ....t""=' ~ ¥~?'..~,; ~'~.'" '~:?.e'~ .~r~'~? ~,~ 7:~.-:.i.~.,,.-,~?';.~.,~=~. ?..~:~f.=...~.::~.-.,~:~..~ ~:. '.J6::' : 8394.53~.: .>'~.!..~00~ 19.760 164.3901~: ~2~,::~,; ~;~! ~, ..;2805,6~:.S== ~;.~+;5~:.E. 3 May, 2001- 15:55 - 1- DrillQuest Milne Point Unit Alaska Drilling & Milne Plan: MPC~4~-~~p2 OSAL REPORT 7 May, 2001 Surface Coordinates: 6029452.34 N, 558013.45 E (70° 29' 27.7850" N, 149° 31' 32.6858" W) Kelly Bushing: 45. lOft above Mean Sea Level ORIEL. lNG SERVICES A Halliburton Company Proposal Reft pro9829 Milne Point Unit Measured Depth (ft) Azim. 0.00 0.000 0.000 100.00 0.000 0.000 159.10 0.000 0.000 200.00 0.000 0.000 300.00 0.000 0.000 400.00 1.000 85.000 500.00 2.000 85.000 600.00 3.000 85.000 700.00 4.000 85.000 800.00 5.329 93.654 900.00 6.730 98.792 1000.00 8.166 102.149 1100.00 9.621 104.502 1125.86 10.000 105.000 1200.00 11.048 107.038 1300.00 12.479 109.247 1 400.00 13.925 111.005 1 500.00 15.380 112.438 1600.00 16.843 113.628 1700.00 18.312 114.6,33 Sub-Sea Vertical Depth Depth (ft) (ft) Sperry-Sun Drilling Services Proposal Report for Plan: MPC-24 - MPC-24 Wp2 Local Coordinates Global Coordinates Dogleg Northings Eastings Northings Eastings Rate (ft) (ft) (ft) (fi) (°/lOOft) -46.10 0.00 0.00 N 53.90 100.00 0.00 N 113.00 159.10 0.00 N 153.90 200.00 0.00 N 253.90 300.00 0.00 N 3,53.89 399.99 0.08 N 4,53.86 499.96 553.76 599.86 653.58 699.68 753,24 799,34 .~ ~-~'-_~,~ 852,6~ ~-0,03 N 951,84~_~~' 9~ ~_ 2,36 S 1050,64 ~10~__ ~'- 5,95 S 1076,12 ~~2 7,07 S 1149,01 ~9---~'-5,11 10,82 S 1246.91 1293.01 17.18 S 1344.26 1390.36 25.06 S 1441.01 1467.11 34.43 S 1537.08 1583.18 45.30 S 1632.41 1678.51 57.66 S 1746.69 19.000 115.050 1676.64 1722.74 1800.00 19.000 115.050 1727.05 1773.15 1813.70 19.000 115.050 1740.00 1786.10 1900.00 19.000 115.050 1821.60 1867.70 1987.04 19.000 115.050 1903.90 1950.00 2000.00 19.259 115.050 2087.04 21.000 115.050 0.00 E 6029452.34 N ~013.45 E 0.00 E 6029452.3~t~ ~--~:~_ 5E~013.45 E 0,03 E 602945~ ~013,45 E 0,00E 602~134~ ~13,45E.. 0.00 E ~~ ~13.45 E ~_ 0,87 ~ ~452,4~1 558014,32 E ~46~ 6029452,67 N 558016,92 E ~ 6029453,09 N 558021,27 E 13,90 E 6029453,66 N 558027,34 E 22.01 E 6029453.74 N 558035.45 E 32.44 E 6029452.63 N 558045.89 E 45.17 E 6029450.34 N 558058.64 E 60.21 E 6029446.86 N 558073.70 E 64.47 E 6029445.78 N 558077.97 E 77.48 E 6029442.13 N 558091.01 E 1916.14 1962.24 1997.86 2043.96 96.84 E 6029435.91 N 558110.42 E 1182.8 E 6029428.20 N 558131.92 E 141.77 E 6029419.01 N 558155.48 E 167.30 E 6029408.34 N 558181.10 E 194.85 E 6029396.20 N 558208.75 E 63.93 S 208.41 E 6029390.03 N 558222.35 E 71.28 S 224.13 E 6029382.81 N 558238.13 E 73.17 S 228.17 E 6029380.95 N 558242.18 E 85.07 S 253.62 E 6029369.25 N 558267.73 E 97.07 S 279.30 E 6029357.46 N 558293.50 E 2100.03 21.51 2 115.285 2009.94 2056.04 2200.00 25.468 116.795 2101.64 2147.74 2300.00 29.435 117.921 2190.36 2236.46 98.86 S 263.14 E 6029355.69 N 558297.36 E 111.55 S 310.28 E 6029343.22 N 556324.59 E 113.54 S 3i 4.53 E 6029341.25 N 558328.86 E 131.07 S 350.32 E 6029324.00 N 558364.78 E 152.28 S 391.24 E 6029303.12 N 558405.86 E 0.00 0.00 0.00 0.00 1.00 1.00 1.00 1.00 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 0.00 0.00 0.00 0.00 2.00 2.00 4.00 4.00 4.00 Vertical Section 0.00 0.00 0.00 0.00 0.00 0.56 2.23 5.02 8.93 14.63 22.82 33.49 46.62 50.42 62.24 80.40 101.09 124.29 149.99 178.16 192.16 208.45 212.64 239.01 265.61 269.60 297.71 302.13 339.77 383.65 Alaska Drilling & Wells Milne Point MPC Comment 20" Conductor Begin Dir @ 1.00°/100ff· 300.0Oft MD 300.OOft TVD ~ Dir Rate Increase @ 1.50°/100ft · 700.00ftMD,699.68ftTVD End Dir, Start Sail @ 19.000° ' '~'.~ 1746.69ftMD,1722.74ftTVD Base Permafrost Begin Dir @ 2.00°/10Oft· 1987.04ft MD, 1950.00ft TVD Dir Rate Increase @ 4.00°/100ft' 2087.04ftMD,2043.96ftTVD 7 May, 2001 - 15:26 Page 2 of 8 DrillQuest 2.00.08.006 Sperry-Sun Drilling Services Proposal Report for Plan: MPC-24 - MPC-24 Wp2 Milne Point Unit Measured Depth (It) Incl. Azim. Sub-Sea Vertical Depth Depth (ft) (it) 2332.59 30.730 118.230 2218.56 2264.66 2400.00 30.730 118.230 2276.51 2322.61 2500.00 30.730 118.230 2362.46 2408.56 2600.00 30.730 118.230 2448.42 2494.52 2700.00 30.730 118.230 2534.38 2580.48 2800.00 30.730 118.230 2620.34 2666.44 2900.00 30.730 118.230 2706.30 2752.40 3000.00 30.730 118.230 2792.26 2838.36 3100.00 30.730 118.230 2878.21 3200.00 30.730 118.230 2964.17 3300.00 30.730 118.230 3400.00 30.730 118.230 3500.00 30.730 118.230 3600.00 30.730 118.230 3700.00 30.730 118.230 3800.00 30.730 118.230 3900.00 30.730 118.230 4000.00 30.730 118.230 4100.00 30.730 118.230 4200.00 30.730 118.230 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (it) (it) (ft) (ft) 159.97 S 176.26 S 200.43 S 224.60 S 248.78 S 272.95 297_~12~S~ 3~' .--Z 405.65 E 6029295.54 N_._ 558420.33 E 436.00 E 602927~ ~-558450.81 E 481.02 E --602~'66~..___ 5~96.02 E 526.04 E ~~~5.~ ~41.23 E ~ ~ ~~ 558586.44 E ~<~_ !6.08 ~ ~'~9184.21 ~ 558631.64 £ ~10_ ~ ~ ~29100.39 N 558676.85 £ 7-~ 6029136.57 N 558722.06 E 2924.31 ~'~_ = 751.15 E 6029112.75 N 558767.27 E 3010.27 . ~-~9~_ _S ~;~; 796.17 E 6029088.93 N 558812.48 E 3050.13 _~.~-~ ~:~'3__~J~O~S 841.1 9 E 6029065.12 N 558857.69 E 3136.0~~_~1 ~. ~17.97 S 886.21 E 6029041.30 N 558902.90 E 3222.05~_ 32~ ~ 442.14 S 931.23 E 6029017.48 N 558948.10 E 3308.01 ~_..~_33~1 ~:' 466.31 S 976.25 E 6028993.66 N 558993.31 E 3393.97 ~7 490.48 S 1021.28 E 6028969.84 N 559038.52 E 3479.92 3526.02 3565.88 3611.98 3651.84 3697.94 3737.80 3783.90 3823.76 3869.86 4300.00 30.730 118.230 3909.72 3955.82 4400.00 30.730 118.230 3995.68 4041.78 4500.00 30.730 118.230 4081.63 4127.73 4600.00 30.730 118.230 4167.59 4213.69 4614.43 30.730 118.230 4180.00 4226.10 4700.00 30.730 118.230 4253.55 4299.65 4800.00 30.730 118.230 4,339.51 4385.61 4900.00 30.730 118.230 4425.47 4471.57 4928.54 30.730 118.230 4450.00 4496.10 5000.00 30.730 118.230 4511.43 4557.53 514.65 S 1066.30 E 6028948.02 N 559083.73 E 538.82 S 1111.32 E 6028922.20 N 559128.94 E 562.99 S 11 56.34 E 6028898.39 N 559174.15 E 587.16 S 1201.36 E 6028874.57 N 559219.35 E 611.33 S 1246.38 E 6028850.75 N 559264.56 E 635.50 S 1291.40 E 6028826.93 N 559309.77 E 659.68 S 1336.42 E 6028803.11 N 559354.98 E 683.85 S 1381.45 E 6028779.29 N 559400.19 E 708.02 S 1426.47 E 6028755.47 N 559445.40 E 711.51 $ 1432.97 E 6028752.04 N 559451.92 E 732.19 S 1471.49 E 6028731.66 N 559490.61 E 756.36 S 1516.51 E 6028707.84 N 559535.81 E 780.53 S 1561.53 E 6028684.02 N 559581.02 E 787.43 S 1574.38 E 6028677.22 N 559593.93 E 804.70 S 1606.55 E 6028660.20 N 559626.23 E Dogleg Rate (°llOOff) 4.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Vertical Section 399.26 432.20 481.06 529.93 578.80 627.66 676.53 725.40 774.26 823.13 872.00 920.86 969.73 1018.60 1067.46 1116.33 1165.20 1214.06 1262.93 1311.80 1360.67 1 409.53 1458.40 1 507.27 1514.32 1556.13 1605.00 1653.87 1667.81 1702.73 Alaska Drilling & Wells Milna Point MPC Comment End Dir, Start Sail @ 30.730° · 2332.59ftM D,2264.66ftTVD SBF1-NB TSBB-OB 7 May, 2001 - 15:26 Page 3 of 8 DrillQuest 2,00.08o006 Sperry-Sun Drilling Services Proposal Report for Plan: MPC-24 - MPC-24 Wp2 Milne Point Unit Measured Depth (ft) Azim. Sub-Sea Depth {ft) 5044.87 30.730 118.230 4550.00 5100.00 30.730 118.230 4597.38 5200.00 30.730 118.230 4683.34 5300.00 30.730 118.230 4769.30 5400.00 30.730 118.230 4855.26 5500.00 30.730 118.230 4941.22 5600.00 30.730 118.230 5027.18 5613.41 30.730 118.230 5038.70 5700.00 32.244 126.002 5112.57 5800.00 34.529 134.093 5196.11 5900.00 37.285 141.213 6000.00 40.416 147.435 6100.03 43.838 152.874 6200.00 47.488 157.656 6300.00 51.314 161.898 6364.34 53.650 164.390 Vertical Depth (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 4596.10 815.55 S 4843.48 828.87 S 4729.44 853.04S 4815.40 877.21S 4901.36 901.38S 4987.32 925.55 5073.28 949.72 5084.80 95~ 51 68.67 9~ 5242.21 -- _ ..... 5277.13 ~_-~5323.~~--~ ~ O~r~80~ 5355.0x,~_~~1~. ~.76 5~3.28 ~49.~ 6400.00 53.850 164.390 5624.32 5670.42 6500.00 53.850 164.390 5683.31 5729.41 6600.00 53.850 164.390 5742.30 5788.40 6703.00 53.650 164.390 5801.29 5847.39 6800.00 53.850 164.390 5860.28 5906.38 6894.49 53.850 164.390 5916.02 5962.12 6900.00 53.574 164.390 5919.28 5965.38 7000.00 48.574 164.390 5982.09 6028.19 7103.00 43.574 164.390 6051.44 6097.54 7203.00 38.573 164.390 6126.81 6172.91 7300.00 33.573 164.390 6207.61 6253.71 7331.45 32.000 164.390 6234.05 6280.15 7400.00 32.000 164.390 6292.18 6338.28 7500.03 32.000 164.390 6376.99 6423.09 1350.02 S 1626.76 E 6028649.51 N___ ~9646.52 E 1651.57 E 6028636.38 ~--_ 5~9671.44 E 1696.60 E 60286_~ ~716.65 E 1741.62 E 60285~.74 ~ 5~_~_761.86 E 1786.6__~4 S ~-~6~___~ ~07.07 S ___ _ ~1.66 E ~28~41 .~ 559852.27 E ~6.68 ~__ --~517.29r N 559897.48 E 'ffi~tZ72~ 6028514.09 N 559903.55 E 1920.92 E 6028490.34 N 559941.93 E 1962.88 E 6028455.24 N 559984.17 E 2002.23 E 6028412.19 N 560023.86 E 2038.68 E 6028361.52 N 560060.70 E 2071.94 E 6028303.60 N 560094.41 E 2101.76 E 6028238.68 N 560124.74 E 2127.91 E 6028167.86 N 560151.45 E 2142.71E 6028119.08 N 560166.63 E 1377.76S 1455.53S 1533.29 S 1611.06S 2150.46 E 6028091.40 N 560174.59 E 2172.19 E 6028013.81 N 580196.93 E 2193.91 E 6027936.21 N 560219.26 E 2215.64 E 6027858.61 N 560241.60 E 1688.83S 1762.32 S 2237.37 E 6027781.01 N 560263.93 E 2257.90 E 6027707.69 N 560285.03 E 1766.59 S 1841.50 S 1910.64 S 2259.10 E 6027703.42 N 560286.26 E 2280.02 E 6027628.69 N 560307.77 E 2299.40 E 6027559.50N 560327.69 E 1974.10 $ 2O3O.79 S 2047.19 S 2317.07 E 6027496.38 N 560345.85 E 2332.91E 6027439.81N 560362.14 E 2337.49 E 6027423.44N 560366.85 E 2082.18 S 2133.22S 2347.27 E 6027388.54 N 560376.89 E 2361.53 E 6027337.61 N 560391.55 E Dogleg Rate (°1103ff) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 0.00 0.00 0.00 0.00 0.00 0.00 5.00 5.00 5.00 5.00 5.00 5.00 0.00 0.00 Vertical Section 1724.66 1751.60 1800.47 1849.33 1898.20 1947.07 1995.93 2002.49 2046.46 2101.17 2159.66 2221.51 2286.24 2353.35 2422.34 2492.62 2563.13 2633.65 2704.16 2774.67 2841.30 2845.18 2913.09 2975.97 3033.33 3084.73 3099.60 3131.32 3177.60 Alaska Drilling & Wells Milna Point MPC Comment 9 5/8" Casing Begin Dir @ 5.00°/100ft' 5613.41ft MD, 5084.80ft TVD End Dir, Start Sail @ 53.850° · 6364.34ftM D,5649.38ftTVD Begin Dir @ 5.00°/100ft' 6894. ., MD, 5962.12ft TVD End Dir, Start Sail @ 32.000° ' 7331.45ftM D,6280.15ft'l'VD 7 May, 2001 - 15:26 Page 4 of 8 DriliQuest 2.00.08.006 Sperry-Sun Drilling Services Proposal Report for Plan: MPC-24 - MPC-24 Wp2 Milne Point Unit Measured Sub-Sea Vertical Dept~ Incl. Azim. Depth Depth (ft) (ft) (ft) 7517.70 32.000 164.390 6392.00 7600.00 32.000 164.390 6461.79 7667.46 32.000 164.390 6519.00 7700.00 32.000 164.390 6546.60 7702.63 32.000 164.390 6549.00 7731.14 32.000 164.390 6573.00 7761.45 32.000 164.390 6598.71 7800.00 30.651 164.390 6631.64 7818.95 29.987 164.390 6648.00 7900.00 27.151 164.390 6719.17 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 6438.10 2142.25 S 6507.89 2164.26 S 6565.10 2218.68 S 6592.70 2235.29 S 6595.10 2236.74 S 7943.35 25.634 164.390 6758.00 8000.00 23.651 164.390 6809.4~~~ 8100.00 20.151 164.390 6002.2~=. 69~ 8111.17 19.760 164.390 6912.76 ~-.__._69~_. 8131.62 19.760 164.390 6932.00 -~8.10 6619.10 2251.18 S 6644.81 2268.66 S 6677.74 22~~ 6694.10 22~ ~- 6765.27 ~-~S ~ ~3.8o s 2409.72 S 2413.39 S 2420.05S 8157.12 19.760 164.390 6956.00 7002.10 2428.36 S 8200.00 19.760 164.390 6996.36 7042.46 2442.32 S 8241.06 19.760 164.390 7035.00 7081.10 2455.69 $ 8244.53 19.760 164.390 7038.26 7084.36 2456.82 S 8300.00 19.760 164.390 7090.47 7136.57 2474.88 S 8389.82 19.760 164.390 7175.00 7221.10 2504.13 S 8394.53 19.760 164.390 7179.43 7225.53 2505.66S 2364.05 E 2375.79 E 2385.41 E 2390.05 E 2390.__ 45 E ~.49 E ~.81 ~__ ~204.4~N ~ _-~- 2~ 6027185.21 N 2406.78 E 6027176.01 N 2417.21 E 6027138.77 N 6027328.60 N ~0394.15 E 6027286.69 ~% 560406.21 E 602725~ ~416.10 E _60272~_..76 ~ ~20.87 E ~~ 56(N21.28 E ---~ ~ ~-%~ .- ..... ~ ,_-:F= '~'~2~219.~ 560425.43 E 560429.87 E 560435.42 E 560438.06 E 560448.78 E 2422.39 E 6027120.26 N 560454.11 E 2428.75 E 6027097.56 N 560460.64 E 2438.78 E 6027061.72 N 560470.96 E 2439.81 E 6027058.06 N 560472.01 E 2441.67 E 6027051.41 N .560473.93 E 2443.99 E 6027043.13 N 560476.31 E 2447.89 E 6027029.19 N 560480.32 E 2451.63 E 6027015.85 N 560484.16 E 2451.94 E 6027014.73 N 560484.48E 2456.99 E 6026996.71N 560489.67 E 2465.16 E 6026967.52 N 560498.07 E 2465.59 E 6026965.99 N 560498.51E All data is in Feet unless otherwise stated. Directions and coordinates are relaIive to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magn~c Declination at Surface is 26.325° (03-May-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 135.229° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8394.53ft., The Bottom Hole Displacement is 3515.32ft., in the Direction of 135.462° (True). Dogleg Rate (o/melt) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.50 3.50 3.50 3.50 3.50 3.50 3.50 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Vertical Section 3185.79 3223.87 3255.09 3270.15 3271.46 3284.55 3298.58 3316.08 3324.44 3358.28 3375.11 3395.73 3428.30 3431.63 3437.67 3445.20 3457.86 3469.98 3471.00 3487.38 3513.90 3515.29 Alaska Drilling & Wells Milne Point MPC Comment THRZ / TUDZ BHRZ 7" Casing KLGM Begin Dir @ 3.50°/100ft: 7761.45ft MD, 6644.81ft TVD TKUD TKUC End Dir, Start Sail @ 19.760° · 8111.17tiM D,6958.86ftTVD TKA3 TKA2 TMLV MPC-24 Target, Geological OWC Total Depth: 8394.53flM D,7225.53ftTVD 4 1/2" Liner 7 May, 2001 - 15:26 Page 5 of 8 DrillQuest 2.00.08.006 Sperry-Sun Drilling Services Proposal Report for Plan: MPC-24 - MPC-24 Wp2 Milne Point Unit Alaska Drilling & Wells Milne Point MPC Comments Measured Depth (it) 300.00 700.00 1746.69 1987.04 2087.04 2332.59 5613.41 6364.34 6894.49 7331.45 7761.45 8111.17 8394.63 Formation Tops Measured Depth (it) Station Coordinates TVD Northings Eastings (it) (it) (it) 300.00 699.68 1722.74 1950.00 2043.96 2264.66 5064.80 5649.38 5962.12 6280.15 6644.81 6956.86 7225.53 0.00 N 1.22 N 63.93 S 97.07 S 111.55 S 159.97 S 952.96 S 1350.02 S 1762.32 S 2047.19 S 2413.39 S~ ~9.'8-1 E 2505.66 S ~~465.59 E .-__._~ -~.. ~ . : ~ 0.00 E Begin Dir @ 1.00°/100ft' 300.00ftC, 3~0ft 'I'V~ 13.90 E Dir Rate Increase__@ 1.50°/~O~,699.~TVD 208.41 E End Dir, Start ~.~' 1~.6~,1722.74ftTVD 279.30 E Begin Dir @ ~°/100ft :. ~7.~ M~950.00ft TVD 310.28 E Dir Rate Incr.@ 4.~1-~2087.0~,ftMD,2043.96ftTVD~ .__-~_ '~_~_-_ ~ ~ 405.65 E ~~Start S~~30°: 2332.59ftMD,2264.66ftTVD 882.72 E ~n ~.@ 5.00°/100ft: 5613.41ft MD, 5064.80ft TVD 2142.71 ~' ~Dir~ Sail @ 53.850°: 6364.34ftMD,5649.38ftTVD 225~ ~~ Dir @ 5.00°/10Oft: 6894.49ft MD, 5962.12ft TVD 2~9~ ~crDir, Start Sail @ 32.000°: 7331.45ftMD,6280.15ffTVD ~- .-__~- :- Vertical Depth (it) Sub-Sea Depth (it) Begin Dir @ 3.50°/100ft: 7761.45ft MD, 6644.81ft TVD End Dir, start Sail @ 19.760° · 8111.1 7ftMD,6956.86ftTVD Total Depth · 8394.53ftMD,7225.53ftTVD Northings Easfings (it) (it) 1813.70 1786.10 1740.00 73.17 S 228.17 4614.43 4226.10 4180.00 711.51 S 1432.97 4928.54 4496.10 4450.00 787.43 S 1574.38 7517.70 6438.10 6392.00 2142.25 S 2364.05 7667.46 6565.10 6519.00 2218.68 S 2385.41 7731.14 6619.10 6573.00 2251.18 S 2394.49 7818.95 6694.10 6648.00 2295.17 S 2406.78 7943.35 6804.10 6756.00 2351.06 S 2422.39 8131.62 6978.10 6932.00 2420.05 S 2441.67 8157.12 7002.10 6956.00 2428.36 $ 2443.99 Dip Dip Dir. Formation Name Deg. Deg. E 0.000 0.447 Base Permafrost E 0.000 0.447 SBF1-NB E 0.000 0.447 TSBB-OB E 0.000 0.447 THRZ/TUDZ E 0.000 0.447 BHRZ E 0.000 0.447 KLGM E 0.000 0.447 TKUD E 0.000 0.447 TKUC E 0.000 0.447 TKA3 E 0.000 0.447 TKA2 7 May, 2001 - 15:26 Page 6 of 8 DrillQuest 2.00.08.006 Sperry-Sun Drilling Services Proposal Report for Plan: MPC-24 - MPC-24 Wp2 Milne Point Unit Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) Formation Tops (Continued) Northings Eastings (ft) (ft) Dip Dip Dir. Formation Name Deg. Deg. 8241.06 7081.10 7035.00 8389.82 7221.10 7175.00 2455.69 S 2451.63 E 0.000 2504.13 S 2465.16 E 0.000 Casing details From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) <Surface> <Surface> 159.10 <Surface> <Surface> 5044.87 <Surface> <Surface> 7702.83 <Surface> <Surface> 8394.53 · _~..;~:..~ Vertical ':~i~'.:~'~ ~_ _. ~ ..... __ .-: .~...- ..-_: ._~: .. ~~ -~0" ~.1~ ~/8" C~ing 7~ 41/2" Liner Targets associated with this wellpath Target Name Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) MPC-24 Target Mean Sea Level/Global Coordinates: Geographical Coordinates: 7084.36 2456.82 S 2451.94 E 7038.26 6027014.72 N 560484.46 E 70° 29' 03.6166" N 149° 30' 20.5497" W Target Boundary Point #1 7084.36 2478.31 S 2037.28 E #2 7084.36 2633.77 S 2736.08 E #3 7084.36 24,33.97 S 2762.64 E #4 7064.36 2212.41 S 2051.35 E Alaska Drilling & Wells MIIne Point MPC Target Target Shape Type Po~gon Geologic~ 7 May, 2001 - 15:26 Page 7 of 8 DrillQuest 2.00.08.006 Sperry-Sun Drilling Services Proposal Report for Plan: MPC-24 - MPC-24 Wp2 Milne Point Unit Target Name Targets associated with this wellpath (Continued) Target Entry Coordinates TVD Northings Eaetings (ft) (ft) (ft) Mean Sea Level/Global Coordinates #1 7038.~_ ~6026990.00 N #2 70~'-'-_-L~_6 '~- ~'-(~0~6840.00 N #3 -~~_ ~ 60~040.00 N ... ~ #4 ~~- 6027256.00 N Geographical C~inates ~ ~ ~ 70° 29' 03.4064" N --~ ~- ~ 70° 29' 01.8752" N · ~'~-- --~-~ '~-~-.~3 70° 29' 03.8403" N .~% -~;~=~ ~ #4 70° 29' 06.0217" N ..... ~: ~ ~. ~-- __ 560070.00E 560770.00E 560795.00E 560082.00E 149° 30' 32.7492" W 149° 30' 12.1920" W 149° 30' 11.4085" W 149° 30' 32.3330" W Alaska Drilling & Wells Milne Point MPC Target Target Shape Type 7 May, 2001 - 15:26 Page 8 of 8 DrillQuest 2.00.08. 006 Sperry-Sun Anticollision Report Date: 05/07/2001 Time: 16:21:45 Page: I Co-ordinate(N~) Reference: Vertical (TV])) Reference: Comlmay: BP Amoco Reid: Milne Point Reference Site: M Pt C Pad Well: Plan MPC-24, True North Reference Well: Plan MPC-24 MPC-24: RKB (~ 46.1' 46.1 RefereaceWelllmth: Plan*MPC-24 Db: Oracle GLOBAL SCAN APPLIED: Ail wellpaths within 200'+ 100/1000 of reference Reference: Principal Plan & PLANNED PROGRAM ~terpolaflon Method: MD ]me~al: 25,00 ff Er]or Model: ISCWSA Ellipse Depth l~amge: 46.10 to 8394.53 ft Scum Methoa: Trav Cylinder North Ma:dream ]~dins: 1034.84 ff Error Smd'ace: Ellipse + Casing Smwey P~og~am for Deft]drive Welllmth Date: 05/03/2001 Validated: No Version: 4 Plmmed From To Smwey Toolcode Tool Name ff ff 46,10 1046,10 Planned: MPC-24 Wp2 V1 CB-GYRO-MS Camera based gyro multishot 1046.10 8394,53 Planned: MPC-24 Wp2 V1 MWD MWD - Standard Casing Points MD T~J) ])ialaeter Hole Sl~e Name . ff ff ' in in', : ' ' 4991,24 4550,00 9,62 12,25 9 5/8" 7732,19 6620,00 7.00 8.50 7" 8394,53 7225,53 4,50 6,00 4 I/Z' Summary M Pt C Pad MPC-01 MPC-01 Vl 1667,94 1650,00 39,92 36.09 4,06 Pass: Major Risk M Pt C Pad MPC-02 MPC-02 V1 921,43 925,00 62,78 31,19 31,59 Pass: Major Risk M Pt C Pad MPC-03 MPC-03 V1 1103,13 1100,00 235,68 30,89 204,81 Pass: Major Risk M Pt C Pad MPC-04 MPC-04 V1 647,89 650,00 182,76 21,37 161,39 Pass: Major Risk M Pt C Pad MPC-06 MPC-06 V1 1449,10 1375,00 508.69 35,42 473,81 Pass: Major Risk M Pt C Pad MPC-07 MPC-07 V1 1208,42 1225,00 80,74 35,84 44,91 Pass: Major Risk M Pt C Pad MPC-08 MPC-08 V1 t418,16 1450,00 321.22 45,20 276,02 Pass: Major Risk M Pt C Pad MPC-09 MPC-09 V2 897,78 900,00 51,19 22,98 28,23 Pass: Major Risk M Pt C Pad M PC-10 MPC-10 V1 1819,98 1800.00 225,05 43,19 181,92 Pass: Major Risk M Pt C Pad MPC-11 MPC-11 V1 1916,77 1875,00 77,02 49,75 30,46 Pass: Major Risk M Pt C Pad MPC-12 MPC-12 V9 2079,03 2175,00 67,20 63,25 4,14 Pass: Major Risk M Pt C Pad MPC-12 MPC-12APB1 V6 2079,00 2175,00 67.23 63.32 4.10 Pass: Major Risk M Pt C Pad MPC-12 Planft3 MPC-12A V0 Plan 2079,00 2175,00 67.23 63,32 4,10 Pass: Major Risk M Pt C Pad MPC-13 MPC-13 V4 2170,05 2125,00 109,62 46.63 61,04 Pass: Major Risk M Pt C Pad MPC-14 MPC-14 V1 3324,96 3200.00 195.50 142.42 82.75 Pass: Major Risk M Pt C Pad MPC-15 MPC-15 V1 2513,03 2425,00 284,68 58,34 226,37 Pass: Major Risk M Pt C Pad MPC-17 MPC-17 V1 929,78 925,00 183,82 32,35 151,47 Pass: Major Risk M Pt C Pad MPC-20A MPC-20A V3 Plan: Defin 2285,58 2225,00 136,32 50,77 85,57 Pass: Major Risk M Pt C Pad MPC-20 MPC-20 V1 2285,58 2225,00 136,32 50,66 85,68 Pass: Major Risk M Pt C Pad MPC-21A MPC-21A V3 Plan: Defin 1188,70 1175,00 154,24 30,82 123,62 Pass: Major Risk M Pt C Pad MPC-21 MPC-21 V1 1188,70 1175,00 154,24 30,82 123,62 Pass: Major Risk M Pt C Pad MPC-23 MPC-23 V1 994,42 1000,00 127,06 26,74 100,42 Pass: Major Risk M Pt C Pad MPC-25A MPC-25A V1 749,16 750,00 15,03 9,91 5,13 Pass: Minor 1/200 M Pt C Pad MPC-25 MPC-25 V1 749,16 750,00 15,03 9,91 5,13 Pass: Minor 1/200 M Pt C Pad MPC-26 MPC-26 V1 822,56 825,00 87.27 21.90 65,43 Pass: Major Risk M Pt C Pad MPC-28 MPC-28 V1 1573,18 1575,00 261,56 36,11 225,46 Pass: Major Risk M Pt C Pad MPC-32 MPC-32 V2 Plan: Defini 424,38 425,00 150,71 11,1 9 139,51 Pass: Major Risk M Pt C Pad MPC-36 MPC-36 V3 995,31 1000,00 207,44 27,85 179,67 Pass: Major Risk M Pt C Pad MPC-39 MPC-39 V3 1909,14 1875,00 306,13 37,99 268,13 Pass: Major Risk Site: M Pt C Pad Wen: MPC-01 Rule Assigned: Major Risk Wellpath: MPC-01 V1 Inter-Site Error: 0,00 Reference. MD ' TVD ft ft OffSet semi. Major Axis, , Cfr-Cfr No-Go ~ · .'.~v~' .'Ref on~. ~r°*~.z~ ~r°-ns c"~''. m,~ce .... .ff . .. ff ' lt... · .. deg' deg 'in .ff ft. Allowable Deviation. warning ff 50,00 50,00 50,00 50,00 0,01 0,08 91,10 91,10 75,00 75,00 75,00 75,00 0,09 0,13 91,14 91,14 100.00 100,00 100.00 100,00 0,17 0,17 91,21 91,21 125,00 125,00 125,00 125,00 0,31 0,33 91,29 91,29 149,99 149.99 150,00 149,99 0,46 0,44 91,39 91,39 190,15 1,24 188,91 Pass 190,14 1,85 188,29 Pass 190,13 2,48 187,65 Pass 190,10 3,63 186.46 Pass 190,07 4,61 185.46 Pass , ' STATE OF ALASKA ALASKA{ ,L AND GAS CONSERVATION COM~, SION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [].,I;~velopment Oil la. Type of work [] Re-Entry [] Deepen! [] Service [] Development Gas [] Single Zone ,,,[2[ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field an/Pool BP Exploration (Alaska) Inc. Planned KBE = 46.10' Miln,ed:~oint Unit / Kuparuk 3. Address 6. Property Designation Ri)~r Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL047437 / 4. Location of well at surface 7. Unit or Property Name 1/. Type Bond (See 20 AAC 25.025) 1171' NSL, 2446' WEL, SEC. 10, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 5250' NSL, 325' WEL, SEC. 15, T13N, R10E, UM MPC-24/ Number 2S100302630-277 At total depth 9. Approximate spud d/at'e 3945' NSL, 5264' WEL, SEC. 14, T13N, R10E, UM 06/04/0y' Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acre~ in property 15. Proposed depth (MD and TVD) ADL025516, 14' MDI No Close Approach 2~60 8395' MD / 7226' TVD 16. To be completed for deviated wells 17. Anticipate/d~3ressure {see 20 AAC 25.035 (e) (2)} , Kick Off Depth 300' MD Maximum Hole Angle 53.5 ° Maximun~urface 3885 psig, At total depth (TVD) 6573 / 4542 psig 18. Casing Program Specifications Setti[;~ Depth Size Top ,/ Bottom quantity of Cement Hole Casinq Wei.qht Grade CoUplin.q Lenqth MD 'I',~D MD TVD (include sta.qe data) 30" 20" 92# H-40 Welded 80' 30' //30' 113' 113' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 4781' 30' / 30' 4781' 4663!.' ~91 sx AS Lite, 406 sx Class 'G' 8-1/2" 7" 26# L-80 BTC 7580' 30'/' 30' 75.80' . #'t3~t~ 179 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 BTC 845' 75,S'0' 6465' 8395' ( 7225' 117 sx Class 'G' / / 19. To be completed for Redrill, Re-entry, and Deepen Operation~. ~. _ Present well condition summary / (~ Total depth: measured feet ~lugs (measured) true vertical feet Effective depth: measured feet / Junk (measured) true vertical feet / Casing Length /Size Cemented MD TVD Structural Conductor Surface Intermediate ~ ,_... q...'~ '~//' ~ r=,, ,Production / _ ~..,,_( ~'~...~ "~,{ \'~ Liner / 'C:'~'}~"~ ~'- '7~ '"' X ....~L...~5... ~' MAY 16 Z001 / · Alaska Oil & Gas'Cons Commission Perforation depth: measured / _ , · ~ncnorage true verticaF 20. Attachments [] Filing F~fe [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drillinpluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: J~mes Franks,,...~64,-~468 Prepared By Name/Number: Sondra Stewman, 564-4750 21. I hereby certify that the f~;~/~9'bing is tlcg,~'nd.~orrect to the best of my knowledge Signed SteveShultz /~-~'-//'~ .~'~,~z/~t--- Title Senior Drilling Engineer Date c.~~/' .. . .~ . 1( , .'~ T .¥L.. ' .".i:.':'.. ::' '. v ... ::.'.':..:..:..~ .i.': :.:.::"'..'. :::' .; ':~:~';I./:'"'.':'.. '.' :':'~. ;:"':~:;'....' ~':'..." ..i:..:...~~.,:~ .:~,,,,.:.:c~mmtssiari ~u~e;oifly:.! .::: :. :..: :',: :., i!'...~.,.,::: ;,:: ~..~ :. ,,,~.:.: ::::'...::.:..::.:::...::........ "'l~ermii Number. '"' /" I Apl N~Jml~"e~ ' ' '"'"'"'"' .... "'""'" ' '1" ' 'API:;~V'~.i'~Da;e'' '"l'Se~ C~v~ri'etter '" ' .... .. - ~'/ / 150' <~ ~" I I for other requirements Conditions of Approv/~l: Samples Required [] Yes ~1 No Mud Log Required [] Yes [] No / H~y,drogen Sulfide Measures .1~ Yes [] No Directional Survey Required ]~ Yes [] No .' Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K [] 3.5K psi for CTU Other: by order of Approved By Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate 1. Well Plan Summary MPC-24 Drillin~l Permit IwellName: IMPC-24 I Type of Well (producer or injector): I Grassroots Producer Surface Location: 1171' FSL, (4108' FNL), 2446' FEL (2833' FWL), SEC. 10, T13N, R10E X = 558013 Y = 6029452 C-24 Target Start: 5250' FSL, (29' FNL), 325' FEL (4953' FWL), SEC. 15, T13N, R10E X = 560145 Y = 6028268 Z = 5600' TVDss C-24 Intermediate Target: 4199' FSL, (1079' FNL), 55' FEL (5223' FWL), SEC. 15, T13N, R10E X = 560425 Y = 6027220 Z = 6570' TVDss C-24 Intermediate Target: 4128' FSL, (1150' FNL), 36' FEL (5242' FWL), SEC. 15, T13N, R10E X = 560445 Y = 6027149 Z = 6650' TVDss C-24 Target End: 3994' FSL, (1285' FNL), 5278' FEL (1' FWL), SEC. 14, T13N, R10E X = 560484 Y = 6027015 Z = 7035' TVDss C-24 Target (Bottom Hole Location): 3945' FSL, (1334' FNL), 5264' FEL (14' FWL), SEC. 14, T13N, R10E X = 560498 Y = 6026966 Z = 7175' TVDss ~ Nabors 22E J Estimated Start Date: I June 4, 2001 I Operatin~l days to complete: I 14 I [ MDrkb ~ 8395' ~ I TVDrkb(TD) I 7226'1 ! Max. Inc. 53J_~.5° ~ Well Design (conventional, slim hole, etc.): I Ultraslimhole Grassroots Producer Well Scope: I Drill and Complete a producing well in the Kuparuk sands. Version #1, 5/7/2001 MPC-24 Drillin~l Permit 2. Current Well Information 2.1 General 2.2 Well Name: MPC-24 APl Number: Well Type: Current Status: BHP: BHT: MPC-24 Development- Kuparuk Producer Conductor Set 4542 psi @ 6573' TVDss Kalubik silts. Abnormal pressure gradient 170°F @ 7000' TVDss Estimated (SOR) Current Mechanical Condition MPC-24: Nabors 22E: Conductor: Cellar Box above MSL = 16.2' KB / MSL = 45.3' 20", 92 Ib/ft, H-40 Welded set at 113' MD 3. Drilling Hazards and Contingencies MPC-24 Drillin~l Permit 3.1. Well Control MANDATORY WELL CONTROL DRILLS: Drill Type Frequency Comments D1 Tripping (1) per week, per crew Conducted only inside casing. D2 Drilling (1) per week, per crew Either in cased or open hole. DO NOT shut-in well in open hole. D3 Diverter N/A N/A D4 Accumulator Prior to spud or RWO Approx. every 30 days, thereafter at convenient times. D5 Well Kill Prior to drill out, Prior to drill out the intermediate and production strings. Never per crew carry out this drill when open hole sections are exposed. 3.2. Kick tolerance 3.2.1. The 9-5/8" casing will be cemented to surface. The top of the 15.8 lb/gal tail cement slurry is planned to be 4114' MD. 3.2.2. The Kick Tolerance for the 9-5/8" surface casing, based on the 9.0 ppg expected pore pressure, is 65.9 bbls with an 11.5 ppg FIT. 3.2.3. The Kick tolerance for the 7" intermediate casing, based on the maximum 13.3 ppg pore pressure, is INFINITE with a 14.8 ppg FIT. 3.3. Lost Circulation 3.3.1. Lost circulation has been encountered in the C Pad wells attributable to the "Breathing" in the Milne Point field while cementing Iongstring casing jobs. No lost circulation is expected due to top setting the Kuparuk interval. 3.3.2. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. 3.4. Expected Pressures 3.4.1. The Pad Data Sheet documents numerous instances of over pressure. Abnormal pressures are present both in and above the Kuparuk zone in the heavily developed portion of the C pad area and have required mud weights as high as 13.8 ppg. These high-pressure intervals are a result of water and gas injection in the greater 'C' pad area. 3.4.2. The C-24 well is designed with the anticipation of encountering abnormally pressured formations below the base of the HRZ. Based on the offset well information, the anticipated mud weight should be 10.5 ppg and as high as 13.8 ppg. A full string of 7" casing will be run just below the base of the HRZ formation prior to drilling into potentially pressured Kuparuk sands. 3.5. Pad Data Sheet 3.5.1. Please Read the C-Pad Data Sheet thoroughly. 3.6. Breathing 3.6.1. Breathing/lost circulation is well documented at Milne Point between the Schrader Bluff and the 3 MPC-24 Drilling Permit HRZ when mud weights reach 11.5 ppg. If well bore breathing/lost circulation occurs on C-24, the Alaska Drilling and Wells RP "Well Bore Breathing" will be followed. As stated in that RP, it is ADW policy that any flow from the well will be treated as a well control problem until a definitive well bore breathing diagnosis is made. This is especially important on C-24 due to the history of abnormal pressures at 'C' pad. 3.7. Hydrocarbons 3.7.1. Hydrocarbons will be encountered in the Kuparuk intervals. 3.8. Faults 3.8.1. No Faults should be crossed along the designed well profile, however should the base of the HRZ come in 80' Iow, then there is the possibility that we might have crossed a major NW-SE fault. At this point we will need to stop drilling and evaluate how to get back into the targeted upthrown target. 3.11 Hydrogen Sulfide 3.11.1. MPC Pad is not designated as an H2S Pad. Below is a summary of the most recent H2S readings: Well E- Well Type H2S Status Date taken I KUP Prod 4.8 May 2000 3 KUP Prod <2.00 Feb 2000 4 KUP Prod 6,30 Apr 2000 5 KUP Prod 6.8 May 2000 6 WAG Shut In Feb 2000 7 KUP Prod 5.7 May 2000 9 KUP Prod <2.00 Feb 2000 14 KUP Prod 19.8 May 2000 15 WAG <2.00 Apr 2000 19 WAG Shut In Feb 2000 22 KUP Prod 3.20 Apr 2000 25 WAG Shut In Feb 2000 4. Drilling Program Overview MPC-24 Drillin~l Permit 4.1. Surface and Anti-Collision Issues Surface Shut-in Wells: No wells need to be shut-in for the rig move on and off MPC-24 Close Approach Wells: There are no close approach wells. Close Tolerance Wells: There are close tolerance wells in drilling the surface hole. The closest well is listed below. Well Name Current Production Precautions Status Priority C-25/C-25A Prod N/A Risk assessment to be conducted. Gyro to be run in the surface casin~l. Follow the travelin~l cylinder closely. 4.2. Well Control - Nabors 22E BOP stack Expected BHP Max Exp Surface Pressure BOPE Ratin~! Planned BOPE Test Pres. 4542 psi @ 6573' TVD 3885 psi 13 5/8" 5M *Rams & Valves: 4000 psi/250 psi (estimated) 10.1 psi/ft ~tas ~lradient) Annular: 2500 psi/250 psi 4.3. Mud Program 12-1/4" Surface Hole Mud Properties: Density (PPg) [ Funnel visc I YP 8.6 - 9.6 100 - 150 25 - 60 8-1/2" Intermediate Hole Mud Properties: HTHP N/A Density (PPg) I Funnel visc I YP I HTHP 9.5 - 10.5 40 - 52 12 - 20 10 - 12 6-1/8" Production Hole Mud Properties: YP HTHP Density (ppg) I Funnel visc ' 11-13.8J 35-45 12 - 20 10 - 12 Spud - LSND Freshwater Mud pH I API Filtrate 9.0 - 9.5 < 6 LSND Freshwater Mud pH I API Filtrate 8.5 - 9.5 < 6 LSND Freshwater Mud pH I API Filtrate 8.5 - 9.5 < 6 Solids <6.5 LG Solids < 6.5 LG Solids < 6.5 Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1R. MPC-24 Drillin~l Permit 4.4. Formation Markers TVDss TVDrkb Formation Tops MDrkb(ft) (ft) (ft) Pore Pressure (Psi) Estimated EMW(ppg) BPRF 1814 1740 1786 SB F2-NA 4614 4180 4226 1881 8.7 TSBD-OA 4784 4325 4372 1946 8.7 TSBB-OB 4859 4390 4444 SBA5 (base OB) 4882 4410 4467 THRZ ! TUDZ 7518 6392 6438 9.0 BHRZ 7667 6519 6565 KLGM 7731 6573 6619 4542 max. 10.5-13.3 TKUD 7819 6648 6694 TKUC 7943 6758 6804 3250 9.3 TKA3 8132 6932 6978 TKA2 8157 6956 7002 TMLV 8241 7035 7081 9.0 TD 7170 4.5. Casing/Tubing Program Hole Size Csg ! Wt/Ft Grade Conn Length Top Bottom Tb~l O.D. MD / TVDrkb MD / TVDrkb 30" 20" 92# H-40 Welded 80' 30' / 30' , 113'./113' 12-1/4" 9.5/8" 40# L-80 BTC 4781 ' 30, / 30' .478i"./~4663' 8-1/2" 7" 26# L-80 BTC 7580' 30' / 30' 7580'"/'7335' 6-1/8" 4-1/2" 12.6# L-80 BTC 845' 7550'/6465' 8395' / 7225' Tubing 3-1/2" 9.3# L-80 EUE +/- 7550' 30' / 30' 7550 / 6465' 4.6. Cement Calculations 9-5/8" 40 Ib/ft L-80 BTC-M 250% excess over gauge hole in permafrost interval, 30% excess over gauge hole below permafrost A TAM Port Collar will be at 1000' MD as a for cement not dis to surface ~n one sta¢ Total Cement Volume: Wash 50 bbl of Chemical Wash at 8.32 ppg 75 bbl of MUDPUSH Spacer weighted to 10.20 ppg Lead 521 bbl 10.7 Iai AS Lite - 691 sacks Tail 74 bbl 15.8 lb/gal Class G + adds - 406 sacks B~ST = 80° F from SOR, BHCT 70° Casin~l Size I 7" 26 Ib/ft L-80 BTC-M BasisI 30% excess Total Cement Volume: Wash I 20 bbl of Newtonian Chemical Wash (CW100) weighted to 8.32 ppg SpacerI · ~....,.~.!.! ................ ?.~:~:.~,~.~!:....:!..~;.~:~::.l~(?,!~,.:~,!a:,ss:::~..:~.,add~ 7.1.?,.:sack? .................................................................................. . .................................... ... 40 bbl of MUDPUSH Spacer weighted to 12 ppg Temp I BHST = 170° F from SOR, BHCT 130° F estimated MPC-24 Drilling Permit Casing Size I 4-1/2" 12.6 Ib/ft L-80 BTC-M BasisI 30% excess Total Cement Volume: Wash I 20 bbl of Newtonian Chemical Wash (CW100) weighted to 8.32 ppg Spacer Tail 25 bbl 15.8 lb/gal GASBLOK slurry -117 sacks 40 bbl of MUDPUSH Spacer weighted to 14.5 ppg Temp I BHST = 170° F from soR,' BHCT 130° F estimated 4.7. Survey and Logging Program 12 1/4" Hole Section: Open Hole: 8 1/2" Hole Section' Open Hole: 6-1/8" Hole Section: Open Hole: Cased Hole: Dir/GR - Gyro as required Dir / ABGR ! Res / PWD At bit GR is extremely important to mitigate the chances of hitting an over pressured formation. Dir / GR ! Res ! PWD / Neutron ! Dens RFT - 30 pressure points (contin~lent on hole conditions and Iow mud weight) CBL MPC-24 Operations Summary MPC-24 Drillin~l Permit 5,1, Pre-Rig Operations 1. Grade and level pad as needed. 5.2. Procedure 5,3, 1. MIRU, NU diverter on 20" conductor, PU 5" drill pipe 2. Drill 12 4,4" surface hole as per directional plan. Maximum tangent angle 30.73° 3. Condition mud and spot casing running lube pill prior to 9 5/8" casing run. POOH 4. Run and cement 9 5/8" casing from TD to surface. TAM Port Collar as contingency should cement not reach the surface. 5. ND Diverter 6. Install FMC 11" 5m wellhead 7. N/U and test 13 %" 5m BOP 8. Drill 8 Y2" intermediate hole as per directional plan. Maximum angle 50.85° 9. Run and cement 7" casing from 7700' to 6700' MD. 10. Pick up 3 Y2" drill pipe and drill 6 1/8" production hole as per directional plan. Maximum angle 19.3° 11. RIH with RFT for 30 samples should hole conditions allow. 12. Run and cement 4 Y~" liner with 150' overlap. 13. Run 3 Y~" frac completion 14. Freeze protect. 15. ND BOP 16. RDMO Post Rig Work 1. MIRU E-Line 2. Run CBL 3. Perforate Kuparuk interval sands 4. RD E-line 5. Perform fracture treatment on zones. 6. MIRU workover rig 7. Run 2 7/8" ESP completion 8. Freeze protect tubing and annulus 9. RDMO Milne Point C-24: Proposed Completion TREE: 3-1/8" - 5M Cameron WELLHEAD: 11 · - 5M Gen 5A FMC Tubing Hanger: 7-1/16 x 3-1/2 Tubing Head: 11 x 7-1/16 Adapter: 7-1/16 5M x 3-1/8 5M 20", 91.1 #Iff, H-40 @ 113'MD (113' TVD) Cellar Elevation = +16.2' RKB-MSL = +45.3' MW = 9.5 ppg 9-5/8", 40 #Iff, L-80, BTC @ +/- 5045' MD ( 4596' TVD) 3-1/2" 9.3# L-80, EUE Sliding Sleeve for Jet Pump completion 7" x 3-1/2" Production Packer above Liner Top TD @ +/- 7700' MD ( 6600' TVD) -HRZ MW = 9.8 ppg TD @ +/- 8395' MD ( 7225' TVD) - 150' below Miluveach MW = 13.8 ppg 7" x 4-1/2" Liner Hanger and Packer @ 7550' MD 7", 26 #/ft, L-80, BTC-Mod 4-1/2", 12.6 #Iff, L-80, BTC-Mod Date 5-7-01 Rev By Comments JDF Proposed Completion WP Milne Point WELL: C-24 APl NO: 50-029-????? BP Alaska Drilling & Wells ~'13~r'~-=ur'~. [ Milne Point Unit o.,--,.- -..v,=.- Alaska Drilling & Wells Milne Point MPC MPC-24 WP02 I DrillQuest' 20' Conductor MD 159.10' TVD Current Well Properties Well: Horizontal Coordinates: Ref. GIo~al Coordinates: Ref. Structure Reference: Ref. Geographical Coordinates: RKB Elevatio~: North Refererme: Units: MPC-24 WP02 6029452.34 N, 558O13.45 E 2104.91 N, 28.17 W 70~ 29' 27.7850' N, 149° 31' 32.6858' W 45.10ft above Structure Refera3ce True North Feet -6O Begin Dir O 1.00~/100ft: 300.00ft MD, 300.00ft TVD \Dir Rate Increase O 1.50~/100ft: 700.00flMO,699.68ftTVD 8tart Sail 0 19.000~: 1746.69ftMD,1722.74ftTVD Bes~ Pcrrn~[rosl 1786.10' O 4.00'/10~t: 2087.04ftMD,2043.96ftTVO . Start Sail ~ 30.730=: 2332.59flMD~264.66ftTVD C~ -1200 .c_ o Z Draft Copy 5O44.87' MD 4596.10' TVD ....... Sa__F1 -~a 4226.10' T__VD_ T$8B-OB 4496.10' ?VD Begin DIr ~ 5.00~/100ft: 5613.41ff MD, 5084.80ft End Dlr, Start Sai ~ 53.850~: 6364.34flMD,5649.38ft'rVD Dir ~ 5.00~/100ft: 6894.49ft MD, . Start Sail ~ 32.000°: 7331.45ftMO Dir O 3.50°/100ff: 7761.45ft MD, 6644.81ff TVO End Dir, Staxt Sail O 7702.83' MD ~.~.-10~- 'r~o 'THP. Z i TUOZ 6438.1Cr TVD .................... MAC-24 large[ ..... Potyg~n ....... 7084.36' 'rVD ........ 2456.82 S, 2451.94 E ................ I I 1 200 2400 Vertical Section RHP. Z 65~5.10' IV{~ KLGM 6619.10'lVD .... TKUD 6694.10 rVD TKUC 6804.10 TVD -- -- --TKA3 6978.10 TVO - -OWC 7221.10:TVD 4 ~ uner 7225.53' TVD I 3600 0 Scale: linch = 600ft ABW [:)ir O 1.0(Y'/100ft: 300.00ft MD, 300.00ft TVD Start Sail ~ 19.000": 1746.69fflvlD, 1722.74ftTVD in DIr ~ 2.00~/100fl: 1987.04ft MD, 1950.00ff TVO 4.0(Y'/100ff: 2087.04ftMD,2043.96flTVD Dir, Start Sail ~ 30.730°: 2332.59ftMD,2264.66ftTVD 9 5~' Casing 5044.87' MD 4596.10' TVO bp Begin Dir ~ 5.0(Y'/100ft: 5613.41ft MD, End DIr, Start Sail O 53.850°: 6364.34ftMD Begin [:)ir 0 5.00°/100ft: 6894.49ft MD, 5962.12ft 'I'VD End Dir, Start Sail 0 32.000~: 7331.45ftMD,6280.15ft'rvD Begtn Dir ~ 3.50~/100ft: 7761.45ff MD, 6644.81ff TVD End Dtr, Start Sail O 19.760': 8111.17ffMD,6958.86ftTVD MPC-24 Target Polygon ..... 7084.36' ']'VD ........... 2456.82 S, 2451.94 E 7' C_,a~lng 7702.8~ rTVO Total Depth: 8394.53ftMD,7225.53ft'rVD I I I 1 200 1800 2400 · -- -'-ul::asflnns Reference is True No,Ih Proposal Data for MPC-24 Wp2 Well Me~su-emen~ Urfls: ft Nodh fleference: True North vmllca~ Section Descri~ion: wea Ved~ca] S~ion Origin: 0.00 N,0.00 E Mee~u~d ~ Azlm. VerllcalNorthlnga Eaetlr~e VelltoMD~ I:~h I:~h aec'tle~ 0.00 0.000 0.447 0.00 0.00 N 0.00 E 0.00 300.00 0.(X)00.447 300.00 0.00 N 0.00 E 0.00 0.00 700.00 4.000 85.000 699.68 1.22 N 13.90 E 8.93 1.00 112~.8~I0.000105.0'001122.22 7.07 S 64.47 E ~0.42 I.~O 1746.6919.000115.O50 1722.74 63.935 208.41 E 192.16 1.50 19g'/.04 19.000I 15.0501950.00 97.07 S 279.30 F,26S.61 0.00 2G~"7.04 21.000115.050 2043.96 11135S 310.28 E 297.71 ZOO 2332.5930.730118.230 2264.66 159.97 S 405.65 E 399 26 4.{X) 5613.4130.730I 18.2.'q) 50~4.80 952.96 S 1882,72 E2002.49 0.00 6364.3453.850164.300 5649.38 1350.02 S 2142,71 E24~7.48 5.00 6894.4953.850164.3~O 5962.12 1762.32 S 2257.90 E2841 ..10 0.00 7331.4532.000164.390 6280.15 2047.19 S 2.137.49E. 3Ot~.60 5.00 7761.4532.000164.390 f~44.81 22f~.66 S 2398.81 E 3298.58 0.00 8111.1719.760164.390 6958.86 2413.39 S 2439.81 E 3431.63 8244.5319.760164.390 7084.36 2456.82 S 2451.94 E~471.00 0.~O 8394.5319.7(:O 164.390 7225.53 2505.~5 S 2465.59E 3515.29 0.00 Milne Point Unit Alaska Drilling & Wells Milne Point MPC MPC-24 WP02 I DrillQuest MPC-24 Wp2 Formations Measured Vertical Sub-Sea Depth Depth Depth Dip Dip Dir. (ft) (ft) (fi) (Deg) (Deg) Formation Name 1813.70 1786.10 1740.00 0.000 0.447 Base Permafrost 4614.43 4226.10 4180.00 0.000 0.447 SBF1-NB 4928.54 4496.10 4450.00 0.000 0.447 TSBB-OB 7517.70 6438.10 6392.00 0.000 0.447 THRZ / TUDZ 7667.46 6565.10 6519.00 0.000 0.447 BHRZ 7731.14 6619.10 6573.00 0.000 0.447 KLGM 7818.95 6694.10 6648.00 0.000 0.447 TKUD 7943.35 6804.10 6758.00 0.000 0.447 TKUC 8131.62 6978.10 6932.00 0.000 0.447 TKA3 8157.12 7002.10 6956.00 0.000 0.447 TKA2 8241.06 7081.10 7035.00 0.000 0.447 TMLV 8389.82 7221.10 7175.00 0.000 0.447 OWC Draft Copy Single Well Target Data for MPC-24 WP02 Measurement Units: ft Coordinate Target Point TVD TVD Northings Eastings Northings Eastings Target Name Type ss ASP Y ASP X Shape MPC-24 Target Entry Point 7084.36 7038.26 6027014.72 N 560484.48 E 2456.82 S 2451.94 E Polygon Boundary Point A B C D 7084.36 7038.26 6026990.00N 560070.00 E 7084.36 7038.26 6026840.00N 560770.00 E 7084.36 7038.26 6027040.00N 560795.00 E 7084.36 7038.26 6027256.00N 560082.00 E 2478.31S 2633.77 S 2433.97 S 2212.41S 2037.28 E 2736.08 E 2762.64 E 2051.35 E Sperry,Sun Drilling Sei , ices Proposal Data - Plan · MPC-24- MPC-24 Wp2 Draft Copy ,~"..~;::'~. 0.6'6: ;"~?--'.~ -'6-;660":76T.6(~6 '"'~I~'~ .... -6'~6~ .......... 6~'?:~.."-:'.T.'..-:..':"T-'..:.-':. .-' "'::'-.1' :' ...... 6o6! .'..]].~;~:C! 700.00.,]_~ 4.000 ~.O00~&]g~_~'6,8li?.;]i';.'~;6~t.:.!~:Ci;i~-''~ NI~,.,'.?.;:..:13,9i) E .iC ~' ]:1:000! .'.Cc i~5.~-------1;:' .!'"'.'-"'~']~l,:31 i::'.i:~::L'i 1125.86;...~_2s.~] -,0.000 105.0001!:.:i;i.~t:.:.~4~:,s.,,,.l,i?::i,T-.:?.07.1~!?::'-~.:47,::...::....~ i.'5:";i,: 1746.69 "-' 620.83 19.000 115.0501':'1722l:74[;i.?,~?'600'$21:-::~'~: 63"9~'~S?"208 4i E ~.:--."i'f ;1'500~? ~.~..... ..... ~o_-_m..l ,.~...:_.=:_,....:., . ,...:.:. . . ..... . . , ...... , .... ,o. ,,, :rS.",,:' 1967.04 "'.'240.3sl 19.000 115.050i';'~gS0.001:';,~:,'¥'22'~,;26I~'?:::':9707 S!; 2767E) E "~' '~ ~00001'::;':;' oT~---'l'.-':':'~i~,76il ~';'T-~f', ..'-:- .... ~:' ":: i~',~ i~"' "" ":c. ~" ~:: : ' · ";" I. "-'~.-':"- :-: ......... '"""~ ;::':];. B;:;~'i"::i 2332.59 ~ '2 _4~5___._~5]51 30.730 118.230~'! 2264~,;:.:i!:22i)'~'70f;']'~. ~l'-~'~-st-.;.,~:.~lo'-~'~'E I: ;'~,. '~, 4 00i I':?. :" 9',~":' "i'~9~.6i [~-!:,~io'i.':! 636434.7~75093 53850 164390i 5Sil,9~38 i:.... 5r:,458;.;ia50.02§i~-2~6'~'-i'-~~' .O0~TT~-- ": .............. ~:~."':'!?.i?? ' .~ .. ..-- .. ....... .,. .... : ~...-~..~ ........................ !' :~:...?:}i~,.:? 6894.49 . '5,30,~151 53.850 164.390=.' 5962,12[:l]:. :i 3.1~.74[;i'i762;32 SI .225790E ' . 0000' ':.' 0 000'_-_00~)_1i. '2841.30 ~r~l:'t ~TtT'7 .......... ~.;--,,----~ ~!:::;!i"i~2~?~:~;~ 7331.45.=..'.74~]~] 32.000 164-390:"=6260-~"-':~8:03t'."2047:19S72337:49E~:"'""'.":'~'$00~80OOO'~' ~: :: :~'~;**,~i ' .--~. ,--~,.~-~-~ ..... ~;:. ..... ~':~,~ ~,~. ,..'! · -- .-'--- !.., ' .... ~' .----...--~.-. '.'; '.'-~"~-;il...:]~.:.. 01~--~....: 3298.581: .-..I ~:~.~..:3,.,.~.'~= 7761.45 · .430.00 32000 164 390~'"~6644 81''''',:'- 36466'"'2266668 239881E:'", ...... 0000 ~r.,,:;;'*:~":='1:,~ ~'~ ' ~ -- ;';.'.,'.--~..--~ ' .'. ~-~.~,t.--~" ' ' ~ i' ; .... '~"----"'''~'---:'-- ...... ' .... !'??."r'.~!'~ 624453' ~Y~' 19760 164390.':?OS4.,~['"'~*.'~S~I' ~.4,.~'~.Si' ~'4S'~ '" " "'*O ~! '" 0 ' "~,~!", ~-.~ ' ...... ' .... ~ ....... - .... E " ,000 .~ 347"[ .001 · ' .'.:,*' ,.'-:,',.'"' - - · .... ~ ·: ,...,,.: ,.. ~,..:1,~.;;..'~ ..... .. -."., .-. ,[ ....... ?.. ,.... ... ,. .... : .....: · . .., ... ... 3 May, 2001 - 15:55 - 1 - DriilQuest Miine Point Unit Milne Rom Plan: MPC~-MP~Wp2 ..,~..~.~.. ".'.;~ PRO O SAL REPORT .:.'~ .-. 7 May, 2001 Surface Coordinates: 6029452~4 N, 558013.45 E (70° 29'27.7850' N, 149° 31' 32.6858" W) Kelly Bushing: 46.10ft above Mean Sea Level DRILLING SERVICES A Hallibmton Company Proposal Reft pro9829 MIIna Point Unit Measured Depth fit) Incl. Azim. 0.00 0.000 0.000 100.00 0.000 0.000 159.10 0.000 0.000 200.00 0.000 0.000 300.00 0.000 0.000 400.00 1.000 85.000 500.00 2.000 85.000 600.00 3.000 85.000 700.00 4.00O 85.0O0 800.00 5.329 93.654 900.00 6.730 98.792 1000.00 8.166 102.149 1100.00 9.621 104.502 1125.86 10.000 105.000 1200.00 11.048 107.038 1300.00 12.479 109.247 1400.00 13.925 111.005 1500.00 15.380 112.438 1600.00 16.843 113.628 1700.00 18.312 114.6.33 Sub-Sea Vertical Depth Depth (It) ('It) Sperry-Sun Drilling Services Proposal Report for Plan: MPC-24 - MPC-24 Wp2 Local Coordinates Global Coordinates Dogleg Northings Eastings Northings Eastings Rate (It) (ft) (ft) fit) (°/100ft) -46.10 0.00 0.00 N 53.90 100.00 0.00 N 113.00 159.10 0.00N 153.90 200.00 0.00 N 253.90 300.00 0.00 N 3,53.89 399.99 0.08 N 453.86 499.96 Q,3~ 553,.76 599.86 ~~' 653.58 699.68 ~-i~ 753.24799.34 852.69~~,~7~ ~ 0:03 N .... s ? 5.95 s ~076.~2 ~~ 7.07 s 149.01 ~5.11 10.82 S 1246.91 1293.01 17.18 $ 1344.26 1390.36 25.06 S 1441.01 1487.11 34.43 S 1537.08 1583.18 45.30 S 1632.41 1678.51 57.66 S 1746.69 19.000 115.050 1676.64 1722.74 1800.00 19.000 115.050 1727.05 1773.15 1813.70 19.000 115.050 1740.00 1786.10 1900.00 19.000 115.050 1821.60 1867.70 1987.04 19.000 115.050 1903.90 1950.00 2000.00 19.259 115.050 1916.14 1962.24 2087.04 21.000 115.050 1997.86 2043.96 0.00 E 0.00 E 0.00 E 0.00 E 602~.34 N'~ 0.00E ~,~.~ N ? ~_ ~- ~ ..-;..- 0.87 ~3.46~ 6029452.67 N 3.90 E 6029453.6(} N 6029452.34 N ~013.45 E 6029452.34 N~ ~13.45 E 6029452,3~l N. ~5-~13.45 E '~'~13.45 E ~13.45 E 558014.32 E 558016.92 E 558021.27 E 558027.34 E 22.01 E 6029453.74 N 558035.45 E 32.44 E 6029452.63 N 558045.89 E 45.17 E 6029450.34 N 558058.64 E 60.21 E 6029446.86 N 558073.70 E 64.47 E 6029445.78 N 558077.97 E 77.48 E 6029442.13 N 558091.01 E 2100.00 21.512 115.285 2009.94 2056.04 2200.00 25.468 116.795 2101.64 2147.74 2300.00 29.435 117.921 2190.36 2236.46 96.84 E 6029435.91 N 558110.42 E 118.28 E 602942820 N 558131.92 E 141.77 E 6029419.01 N 558155.48 E 167.30 E 6029408.34 N 558181.10 E 194.85 E 602939620 N 558208.75 E 63.93 S 208.41 E 6029390.03 N 558222.35 E 71.28 S 224.13 E 6029382.81 N 558238.13 E 73.17 S 228.17 E 6029380.95 N 558242.18 E 85.07 S 253.62 E 6029369.25 N 558267.73 E 97.07 S 279.30 E 6029357.46 N 558293.50 E 98.86 S 263.14 E 6029355.69 N 558297.36 E 111.55 S 3102.8 E 6029343.22 N 558324.59 E 113.54 S 314.53 E 6029341.25 N 558328.86 E 131.07 S 350.32 E 6029324.00 N 559364.78 E 152.28 S 391.24 E 6029303.12 N 558405.86 E 0.00 0.00 0.00 0.00 1.00 1.00 1.00 1.00 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 0.00 0.00 0.00 0.00 2.00 2.00 4.00 4.00 4.00 Vertical Section 0.00 0.00 0.00 0.00 0.00 0.56 2.23 5.02 8.93 14.63 22.82 33.49 46.62 50.42 62.24 80.40 101.09 124.29 149.99 178.16 192.16 208.45 212.64 239.01 265.61 269.60 297.71 302.13 339.77 383.65 Alaska Drilling & Wells Milne Point MPC Comment 20" Conductor Begin DIr @ 1.00°/100ft: 300.00ft MD Dir Rate Increase @ 1.50°/100ft: 700.00ftMD,699.68ftTVD End Dir, Start Sail @ 19.000°: 1746.69ftMD,1722.74ftTVD Base Permafrost Begin Dir @ 2.00°/100ft: 1987.04ft MD, 1950.00ft TVD Dir Rate Increase @ 4.00°/100ft: 2087.04flM D,2043.96ftTVD 7 May, 2001 - 15:26 Page 2 of 8 DrillQuest 2.00.08.006 Sperry-Sun Drilling Services Proposal Report for Plan: MPC-24 - MPC-24 Wp2 Milne Point Unit Measured (~) Azlm. 2332.59 30.730 118.230 2400.00 30.730 118.230 2500.00 30.730 118.230 2600.00 30.730 118.230 2700.00 30.730 118.230 2800.00 30.730 118.230 2900.00 30.730 118.230 3000.00 30.730 118.230 3100.00 30.730 118.230 3200.00 30.730 118.230 3300.00 30.730 118.230 3400.00 30.730 118.230 3500.00 30.730 118.230 3600.00 30.730 118.230 3700.00 30.730 118.230 3800.00 30.730 118.230 3900.00 30.730 118.230 4000.00 30.730 118.230 4100.00 30.730 118.230 4200.00 30.730 118.230 4300.00 30.730 118.230 4400.00 30.730 118.230 4500.00 30.730 118.230 4600.00 30.730 118.230 4614.43 30.730 118.230 4700.00 30.730 118.230 4800.00 30.730 118.230 4900.00 30.730 118.230 4928.54 30.730 118.230 5000.00 30.730 118.230 Sub-Sea Vertical Depth Depth (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2218.56 2264.66 159.97 S 2276.51 2322.61 176.26 S 2362.46 2408.56 200.43 S 2448.42 2494.52 224.60 S 2534.38 2580.48 248.78 $ 2620.34 2666.44 272.95 2706.30 2752.40 2792.26 2838.36 2878.21 2924.31 34~~ 2964.17 3010.27 .,;: .;3~'~S ~':~.." :/~. 3222.06~ 32¢~s --~-~ 442.14 3308.01%33~ ~ 466.31S 3393.97 ~~7 490.48 S 3479.92 3526.02 514.65 S 3565.88 3611.98 538.82 S 3651.84 3697.94 562.99 S 3737.80 3783.90 567.16 S 3823.76 3869.86 611.33 S 405.65 E 6029295.54 N ~6420.33 E 436.00 E 6029279~4~-N ~50.81 E 481.02 E 602~.66 N'~ ~'~96.02 E 526.04 E ~~!'~85.NL~ ~41.23 E ~E .~"6~08.03'N 558586.44 E ~ ~~ .;.'.= ~16.08 ~ -~--~164.21 N 558631.64 E ~1~10.E;~~-~ 6029160.39 N 558676.85 E ~~- 6029136.57 N 558722.06 E 751.15 E 6029112.75 N 558767.27 E 796.17 E 6029088.93 N 558812.48 E 641.1 9 E 6029065.12 N 558857.69 E 886.21 E 6029041.30 N 558902.90 E 931.23 E 6029017.48 N 558948.10 E 976.25 E 6028993.66 N 558993.31 E 1021.28 E 6028969.64 N 559038.52 E 1066.30 E 6028946.02 N 559063.73 E 1111.32 E 6028922.20 N 559128.94 E 1156.34 E 6028898.39 N 559174.15 E 1201.36 E 6028874.57 N 559219.35 E 1246.38 E 6028850.75 N 559264.56 E 3909.72 3955.82 635.50 S 3995.68 4041.78 659.68 S 4081.63 4127.73 663.85 S 4167.59 4213.69 708.02 S 4180.00 4226.10 711.51 S 1291.40 E 6028826.93 N 559309.77 E 1336.42 E 6026803.11 N 559364.98 E 1381.45 E 6028779.29 N 559400.19 E 1426.47 E 6028755.47 N 559445.40 E 1432.97 E 6028752.04 N 559451.92 E 4253.55 4299.65 732.19 S 4339.51 4385.61 756.36 S 4425.47 4471.57 780.53 S 4450.00 4496.10 787.43 S 4511.43 4557.53 804.70 S 1471.49 E 6028731.66 N 559490.61 E 1516.51 E 6028707.64 N 559535.81 E 1561.53 E 6028684.02 N 559581.02 E 1574.38 E 6028677.22 N 559593.93 E 1606.55 E 6028660.20 N 559626.23 E Dogleg Rate (°llOOft) 4.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Vertical Section 399.26 432.20 481.06 529.93 578.80 627.66 676.53 725.40 774.26 823.13 872.00 920.86 969.73 1018.60 1067.46 1116.33 1165.20 1214.06 1262.93 1311.80 1360.67 1409.53 1458.40 1 507.27 1514.32 1556.13 1605.00 1653.87 1667.81 1702.73 Alaska Drilling & Wells MIIna Point MPC Comment End Dir, Start Sail @ 30.730°: 2332.59ftM D,2264.66ftTVD SBF1-NB TSBB-OB 7 May, 2001 - 15:26 Page 3 of 8 DrillQuest 2.00.08.006 Milne Point Unit Measured Depth (ft) Incl. Azim. 5044.87 30.730 118.230 5100.00 30.730 118.230 5200.00 30.730 118.230 5300.00 30.730 118.230 5400.00 30.730 118.230 5500.00 30.730 118.230 5600.00 30.730 118.230 5613.41 30.730 118.230 5700.00 32.244 126.002 5800.00 34.529 134.093 5900.00 37.285 141.21 3 6000.00 40.416 147.435 6100.00 43.838 152.874 6200.00 47.488 157.656 6300.00 51.314 161.898 6364.34 53.850 164.390 6400.00 53.850 1 64.390 6500.00 53.850 164.390 6600.00 53.850 164.390 6700.00 53.850 164.390 6800.00 53.850 164.390 8894.49 53.850 1 64.390 6900.00 53.574 164.390 7000.00 48.574 164.390 7100.00 43.574 164.390 7200.00 38.573 164.390 7300.00 33.573 164.390 7331.45 32.000 164.390 7400.00 32.000 164.390 7500.00 32.000 164.390 Sperry-Sun Drilling Services Proposal Report for Plan: MPC-24 - MPC-24 Wp2 Sub-Sea Vertical Depth Depth (ft) (ft) Local Coordinates Global Coordinates Dogleg Northings Eastings Northings Fastings Rate (ft) (ft) (ft) (ft) (°/lOOft) 4550.00 4596.10 815.55 4597.38 4643.48 828.87S 4683.34 4729.44 853.04S 4769.30 4815.40 877.21 4855.26 4901.38 901.38S 4941.22 4987.32 925.55 S 5027.18 5073.28 949.72S 1626.76 E 6028649.51 N 559646.52 E 1651.57 E 6028638.38 N~%. ~9671.44 E 1696.60 E 60286~1.~N_ .~----~716.65 E 1741.62 E 6028~'.74~ '~61.86 E 1788.64E r 07.07 E 5831.66 E ~_~__~41 .I;_~N 559852.27 E ~76.6e ~ :~602~517.2{) N 559897.48 E 5038,70 5084.80 952.~ 5112.57 5158.67 9~~ 5196.11 5242.21 ~ ..... 5277.13 5355.0¢~1% %~:76 S 5429.2~ ~1~+~ ~ 1~.94 S 5~4.19 :~~9 1301.12 S 5~3.28 ~49.~ 13~.02 S i¢8~72 ~~ 6028514.09 N 559903.55 E 1920.92 E 6026490.34 N 559941.93 E 1962.88 E 6026455.24 N 559964.17 E 2002.23 E 6028412.19 N 560023.86 E 2038.68 E 6028361.52 N 560060.70 E 2071.94 E 6028303.60 N 560094.41 E 2101.76 E 6028238.88 N 560124.74 E 2127.91 E 6028167.86 N 560151.45 E 2142.71 E 6028119.08 N 560166.63 E 5624.32 5670.42 1377.76 S 5683.31 5729.41 1455.53 S 5742.30 5788.40 1533.29 S 5801.29 5847.39 1611.06 S 21 50.48 E 6028091.40 N 560174.59 E 2172.19 E 6028013.81 N 560196.93 E 2193.91 E 6027936.21 N 560219.26 E 2215.64 E 6027858.61 N 560241.60 E 5860.28 5906.38 1688.83S 5916.02 5962.12 1762.32 S 2237.37 E 6027781.01N 560263.93 E 2257.90 E 6027707.69 N 560285.03 E 5919.28 5965.38 1788.59 S 5982.09 6028.19 1841.50S 6051.44 6097.54 1910.64S 2259.10 E 6027703.42 N 560286.26 E 2280.02 E 6027628.69 N 560307.77 E 2299.40 E 6027559.50 N 560327.69 E 6126.81 6172.91 1974.10 S 6207.61 6253.71 2030.79 S 6234.05 6280.15 2047.19 S 2317.07 E 6027496.38 N 560345.85 E 2332.91 E 6027439.81 N 560362.14 E 2337.49 E 6027423.44 N 560388.85 E 6292.18 6338.28 2082.18 S 6376.99 6423.09 2133.22S 2347.27 E 6027388.54N 560376.89 E 2361.53 E 6027337.61 N 560391.55 E 0.00 0.00 0.00 0,00 0.00 0.00 0.00 0.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 0.00 0.00 0.00 0.00 0.00 0.00 5.00 5.00 5.00 5.00 5.00 5.00 0.00 0.00 Vertical Section 1724.66 1751.60 1800.47 1849.33 1898.20 1947.07 1995.93 2002.49 2046.48 2101.17 2159.66 2221.51 2286.24 2353.35 2422.34 2492.62 2563.13 2633.65 2704.16 2774.67 2641.30 2845.18 2913.09 2975.97 30,33.33 3084.73 3099.60 3131.32 3177.60 Alaska Drilling & Wells Milna Point MPC Comment 9 5/8" Casing Begin Dir @ 5.00°/100ft: 5613.41ft MD, 5084.80ft TVD End Dir, Start Sail @ 53.850°: 6364.34ftM D,5649.38ftTVD Begin Dir @ 5.00°/100ft: 6894. MD, 5962.12ft I'VD End Dir, Start Sail @ 32.000°: 7331.45ftM D,6280.15ftTVD 7 May, 2001 - 15:26 Page 4 of 8 DrillQuest 2.00.08.006 Sperry-Sun Drilling Services Proposal Report for Plan: MPC-24 - MPC-24 Wp2 Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (fi) (ft) (ft) 7517.70 32.000 164.390 6392.00 6438.10 2142.25 S 7600.00 32.000 1 64.390 6461.79 6507.89 2184~6 S 7667.46 32.000 164.390 6519.00 6565.10 2218.68 S 7700.00 32.000 164.390 6546.60 6592.70 2235.29 S 7702.63 32.000 164.390 6549.00 6595.10 2236.74 S 7731.14 32.000 164.390 6573.00 6619.10 2251.18 S 7761.45 32.000 164.390 6598.71 6644.81 2268.68 S 7800.00 30.651 164.390 6631.64 6677.74 2285,,~- 7816.95 29.987 1 64.390 6648.00 6694.10 22 gI~'1.7-~S~- -~ 7900.00 27.151 164.390 6719.17 6765.27 ...:..'2332!~.S '~' .~-'. 7943.3525.634164.390 6758.00_~4. oooo.0323.851164.39o 6~09.4~~ -,.:';m?a.80 s 8111.17 19.760 164.390 6912.76 ~69~ ~ 2413.39 S 8131.62 19.760 164.390 6932.00 ~8.10 2420.05 S 2364.05 E 6027328.60 N 560394.15 E 2375.79 E 6027286.69 N'~_ ~.21 E 2385.41 E 6027252.~3"N~-~~16.10~-~' ---~ E 2390.05 E 60272~.76 N!'~ ~20.87 E 2390.45 E ..'602723~;32 I~.~ ~21.28 E ~.:.~___~._ __- . ~ .'.~ '.... ~:' ,~.4§ E ~ ::'""6027~1gi~":N 560425.43 E ~._.98.81_ E-~ 60'27204.47 N 560429.87 E 2404~E 6027185.21 N 560435.42 E 2406.78 E 6027176.01 N 560438.06 E 2417.21 E 6027138.77 N 560448.78 E 2422.39 E 6027120.26 N 560454.11 E 2428.75 E 6027097.56 N 560460.64 E 2438.78 E 6027061.72 N 560470.96 E 2439.81 E 6027058.06 N 560472.01 E 2441.67 E 6027051.41 N 560473.93 E 8157.12 19.760 164.390 6956.00 7002.10 2428.36 S 2443.99 E 6027043.13 N 560476.31 E 8200.00 19.760 164.390 6996.36 7042.46 2442.32 S 2447.89 E 6027029.19 N 560480.32 E 8241.06 19.760 164.390 7035.00 7081.10 2455.69 $ 2451.63 E 6027015.85 N 560484.16 E 8244.53 19.760 164.390 7038.26 7084.36 2456.82 S 2451.94 E 6027014.73 N 560484.48 E 8300.00 19.760 164.390 7090.47 7136.57 2474.68 S 2456.99 E 6026996.71 N 560489.67 E 8389.82 19.760 164.390 7175.00 7221.10 2504.13 S 2465.16 E 6026967.52 N 560498.07 E 8394.53 19.760 164.390 7179.43 7225.53 2505.68 S 2465.59 E 6026965.99 N 560498.51 E All data is in Feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Easfings are relative to Well. Magnetic Declination at Surface is 26.325° (03-May-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is fronq Well and calculated along an Azimuth of 135.229° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8394.53ft., The Bottom Hole Displacemant is 3515.32ft., in the Direction of 135.462° (True). Dogleg Rate (VlOOft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.50 3.50 3.50 3.50 3.50 3.50 3.50 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Vertical Section 3185.79 3223.87 3255.09 3270.15 3271.46 3284.55 3298.58 3316.08 3324.44 3358.28 3375.11 3395.73 3428.30 3431.63 3437.67 3445.20 3457.86 3469.98 3471.00 3487.38 3513.90 3515.29 Alaska Drilling & Wells Milne Point MPC Comment THRZ / TUDZ BHRZ 7' Casing KLGM Begin Dir ~ 3.50°/100ft: 7761.45ft MD, 6644.81ft 'I'VD TKUD TKUC End Dir, Start Sail @ 19.760°: 8111.1 7ftMD,6958.86ftTVD TKA3 TKA2 TMLV M PC-24 Target, Geological OWC Total Depth: 6394.53ftM D,7225.53ftTVD 4 1/2" Liner 7 May, 2001 - 15:26 Page 5 of 8 DrillQuest 2.00.08.006 MIIne Point Unit Sperry-Sun Drilling Services Proposal Report for Plan: MPC-24 - MPC-24 Wp2 Alaska Drilling & Wells MIIne Point MPC Comments Measured Depth (ft) 300.00 700.00 1746.69 1987.04 2087.04 2332.59 5613.41 6364.34 6894.49 7331.45 7761.45 8111.17 6394.53 Formation Tops Measured (fi) Vertical Depth (ft) 1813.70 4614.43 4928.54 7517.70 7667.46 7731.1 4 7818.95 7943.35 8131.62 8157.12 TVD (ft) Station Coordinates Northings Eastings (ft) (ft) 300.00 699.68 1722.74 1950.00 2043.96 2264.66 5064.80 5649.38 5962.12 6280.15 6844.81 6958.86 7225.53 Comment .. 0.00 N 0.00 E Begin Dir @ 1.00°/100ff: 300.00ft-~6~ 3~0ft~'l~'~ 1.22 N 13.90 E Dir Rate Increase @ 1.50°~~,699.~TVD 63.93 S 208.41 E End Dir, Start ~9.~: 1~.6~,1722.74ftTVD 97.07 S 279.30 E Begin Dir @ ~/1~: ~~U~950.00ff TVD 111.55 S 310.28 E Dir Rate Incr~ @ 4.0~.'_~--J1~.' 2087.0~ftMD,2043.96ftTVD 159.97 S 405.65 E ~~Starl S~~30°: 2332.59ftMD,2264.68ftTVD 952.96 S 1882.72 E ~n ~ @ 5.00/100ft: 5613.41ft MD, 5084.80ft TVD 1350.02 S 2142.71 .~_ ~-~Dir~ Sailo~ 53.850°: 6364.34ftMO,5649.38ftTVD 1762.32 s Di @ s.oo/100.: ffo .4 . UD, 5 2.12. TVD 2047.19 S~~9~ ~cl~Dir, Start Sail @ 32.000 : 7331.45ftUD,6280.15ftTVD 2266.66~. ~9-~ E ~- Begin Dir @ 3.50/10Oft: 7,7o61.45ft MD, 6844.81ftTVD 2413.39 S~ ~9.~ E End Dir, Start Sail @ 19.760 : 8111.17ftMD,6958.86ftTVD 2505.66 S ~.~465.59 E Total Depth · 8394.53ftMD,7225.53ftTVD 1786.10 4226.10 4496.10 6438.10 6565.10 6619.10 6694.10 6804.10 6978.10 7002.10 Sub-Sea Depth (ft) 1740.00 4180.00 4450.00 6392.00 6519.00 6573.00 6648.00 6758.00 6932.00 6956.00 Northlngs Eastings Dip Dip Dir. Formation Name (fi) (ft) Deg. Deg. 73.17 S 228.17 E 0.000 0.447 Base Permafrost 711.51 S 1432.97 E 0.000 0.447 SBF1-NB 787.43 S 1574.38 E 0.000 0.447 TSBB-OB 2142.25 S 2364.05 E 0.000 0.447 THRZ / TUDZ 2218.68 S 2385.41 E 0.000 0.447 BHRZ 2251.18 S 2394.49 E 0.000 0.447 KLGM 2295.17 S 2406.78 E 0.000 0.447 TKUD 2351.06 S 2422.39 E 0.000 0.447 TKUC 2420.05 S 2441.67 E 0.000 0.447 TKA3 2428.36 S 2443.99 E 0.000 0.447 TKA2 7 May, 2001 - 15:26 Page 6 of 8 DrillQuest 2.00.08,006 Sperry-Sun Drilling Services Proposal Report for Plan: MPC-24 - MPC-24 Wp2 Milne Point Unit Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) Formation Tops (Continued) Northings Eastings Dip (ft) (ft) Deg. 8241.06 7081.10 7035.00 8389.82 7221.10 7175.00 2455.69 S 2451.63 E 0.000 2504.13 S 2465.16 E 0.000 Casing de,ails From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) <Surface> <Surface> 159.10 <Surface> <Surface> 5044.87 <Surface> <Surface> 7702.83 <Surface> <Surface> 8394.53 Vertical Depth Ca?l.g'O~. (ft) ~ ~ ~ ..~'i~'. ??,, ~- -~96.1~ ~/8' Casing ~__5.1~ ~'Casing 7~~ 41/2'Uner Dip Dir. Formation Name Deg. .... ~.~_~. 0.447 _oW~;---~i~:~ .... F~? ~ Targets associated with this wellpath Target Name Target Entry Coordinates 'FVD Northinge Eaetlngs (ft) (ft) (ft) MPC-24 Target Mean Sea Level/Global Coordinates: Geographical Coordinates: 7084.36 2456.82 S 2451.94 E 7038.26 6027014.72 N 560484.46 E 70° 29' 03.6166" N 149° 30' 20.5497" W Target Boundary Point #1 7084.36 2478.31 S 2037.28 E #2 7084.36 2633.77 S 2736.08 E #3 7084.36 2433.97 $ 2762.64 E #4 7084.36 2212.41 S 2051.35 E Alaska Drilling & Wells MIIne Point MPC Target Target Shape Type Polygon Geological 7 May, 2001 - 15:26 Page 7 of 8 DrillQuest 2.00.08.006 Sperry-Sun Drilling Services Proposal Report for Plan: MPC-24 - MPC-24 Wp2 Milne Point Unit Target Name Targets associated with this wellpath (Continued) Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) Mean Sea Level/Global Coordinates #1 7038~..~.-~990.00 N #2 70~6 '~ ~840.00 N #3 ~~~.~ 6027040.00 N ~-#4~~- ~.~'~:~' 6027256.00 N Geographical C~inates ~.-$ :~:~-~ ~ ~_ #4 -- 70° 29' 03.4064" N 70° 29' 01.8752" N 70° 29' 03.8403" N 70° 29' 06.0217" N 560070.00 E 560770.00 E 560795.00 E 560082.00 E 149° 30' 32.7492" W 149° 30' 12.1920" W 149° 30' 11.4085" W 149° 30' 32.3330" W Alaska Drilling & Wells MIIne Point MPC Target Target Shape Type 7 May, 2001 - 15:26 Page 8 of 8 DrillQuest 2.00.08.006 Sperry-Sun Anficollision Report Compaay.' BPAmoco Date= 05/07/2~1 Time= 16:21:45 Pa~e: :1 FIdd= Milne Point Reference Site= M Pt C Pad Co-o~ Reference; Well: Plan MPC-24, True North Reference Well: Plan MPC-24 Vertical(TVD) Refer~ce: MPC-24: RKB ~ 46.1' 46.1 Refereace Welilm~: Plan: MPC-24 Db: Oracle GIX)BAL, SCAN APPLIED: All wellpaths within 200°+ 10011000 of reference Reference: Principal Plan & PLANNED PROGRAM InterpolalJon Method: MD Interval: 25.00 ff Error Model: ISCWSA Ellipse Depth Range: 46.10 to 8394.53 ff Scan Method: Trav Cylinder North ~ra~imum Radius: 1034.84 ff Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 05/03/2001 Validated= No Version: 4 Planned From To Survey Toolcode Tool Name ff ff 46.10 1046.10 Planned: MPC-24 Wp2 V1 CB-GYRO-MS Camera based gyro multishot 1046.10 8394.53 Planned: MPC-24 Wp2 V1 MWD MWD - Standard Casing Points MD TVD Diameter Hole ~ze Name ff ff' in in 4991.24 4550.00 9.62 12.25 9 5/8" 7732.19 6620.00 7.00 8.50 7" 8394.53 7225.53 4.50 6.00 4 1/2" Summary <.-- Off~Wellpath > Reference Offset Ctr-~r No=Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning fl ff ff ff ft M Pt C Pad MPC-01 MPC-01 Vl 1667.94 1650.00 39.92 36.09 4.06 Pass: Major Risk M Pt C Pad MPC-02 MPC-02 V1 921.43 925.00 62.78 31.19 31.59 Pass: Major Risk M Pt C Pad MPC-03 MPC-03 V1 1103.13 1100.08 235.68 30.89 204.81 Pass: Major Risk M Pt C Pad MPC-04 MPC-04 V1 647.89 650.00 182.76 21.37 161.39 Pass: Major Risk M Pt C Pad MPC-06 MPC-06 V1 1449.10 1375.00 508.69 35.42 473.81 Pass: Major Risk M Pt C Pad MPC-07 MPC-07 V1 1208.42 1225.00 80.74 35.84 44.91 Pass: Major Risk M Pt C Pad MPC-08 MPC-08 V1 1418.16 1450.00 321.22 45.20 276.02 Pass: Major Risk M Pt C Pad MPC-09 MPC-09 V2 897.78 900.00 51.19 22.98 28.23 Pass: Major Risk M Pt C Pad MPC-10 MPC-10 V1 1819.98 1800.00 225.05 43.19 181.92 Pass: Major Risk M Pt C Pad MPC-11 MPC-ll V1 1916.77 1875.00 77.02 49.75 30.48 Pass: Major Risk M Pt C Pad MPC-12 MPC-12 V9 2079.03 2175.00 67.20 63.25 4.14 Pass: Major Risk M Pt C Pad MPC-12 MPC-12APB1 V6 2079.00 2175.00 67.23 63.32 4.10 Pass: Major Risk M Pt C Pad MPC-12 Plan#3 MPC-12A V0 Plan 2079.00 2175.00 67.23 53.32 4.10 Pass: Major Risk M Pt C Pad MPC-13 MPC-13 V4 2170.05 2125.00 109.62 48.63 61.04 Pass: Major Risk M Pt C Pad MPC-14 MPC-14 V1 3324.96 3200.00 195.50 142.42 82.75 Pass: Major Risk M Pt C Pad MPC-15 MPC-15 V1 2513.03 2425.00 284.68 58.34 226.37 Pass: Major Risk M Pt C Pad MPC-17 MPC-17 V1 929.78 925.00 183.82 32.35 151.47 Pass: Major Risk M Pt C Pad MPC-20A MPC-20A V3 Plan: Defin 2285.58 2225.00 136.32 50.77 85.57 Pass: Major Risk M Pt C Pad MPC-20 MPC-20 V1 2285.58 ~)')5.00 136.32 50.66 85.68 Pass: Major Risk M Pt C Pad MPC-21A MPC-21A V3 Plan: Defin 1188.70 1175.00 154.24 30.82 123.62 Pass: Major Risk M Pt C Pad MPC-21 MPC-21 V1 1168.70 1175.00 154.24 30.82 123.62 Pass: Major Risk M Pt C Pad MPC-23 MPC-23 Vl 994.42 1000.00 127.06 26.74 100.42 Pass: Major Risk M Pt C Pad MPC-25A MPC-25A V1 749.16 750.00 15.03 9.91 5.13 Pass: Minor 1/200 M Pt C Pad MPC-25 MPC-25 V1 749.16 750.00 15.03 9.91 5.13 Pass: Minor 11200 M Pt C Pad MPC-26 MPC-26 V1 822.56 825.00 87.27 21.90 65.43 Pass: Major Risk M Pt C Pad MPC-28 MPC-28 Vl 1573.18 1575.00 261.56 36.11 225.46 Pass: Major Risk M Pt C Pad MPC-32 MPC-32 V2 Plan: Defini 424.38 425.00 1 50.71 11.1 9 139.51 Pass: Major Risk M Pt C Pad MPC-36 MPC-38 V3 995.31 1000.00 207.44 27.85 179.67 Pass: Major Risk M Pt C Pad MPC-39 MPC-39 V3 1909.14 1875.00 306.13 37.99 268.13 Pass: Major Risk Site: M Pt C Pad Well: MPC-01 Rule Assigned: Major Risk Wellpath: MPC-01 Vl Inter-Site Error: 0.00 Reference . Offset Send-Major Axis.. Ctr~r No-Go Allowable MD .TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing Distance Area Deviation ff ff ff . fl fl'.i deg deg in fl ff ff 50.00 50.00 50.00 50.00 0.01 0.08 91.10 91.10 190.15 1.24 188.91 75.00 75.00 75.00 75.00 0.09 0.13 91.14 91.14 190.14 1.85 168.29 100.00 100.00 100.00 100.00 0.17 0.17 91.21 91.21 190.13 2.48 187.65 1 25.00 1 25.00 125.00 1 25.00 0.31 0.33 91.29 91.29 190.10 3.63 186.48 1 49.99 1 49.99 150.00 1 49.99 0.45 0.44 91.39 91.39 190.07 4.61 185.46 Pass Pass Pass Pass Pass I DATE I I CHECKNO'I H ~ 88~ ~4 o4~o~ oo~ee~ VENDOR ALASKAO I LA OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 041801 CK041801I 100. O0 100. O0 PYMT (;OMMENTS' Pe~-mmit to D~'ill ]-ee HANDL]iNO INST' S/H - Te~-~-ie Hubl~le X4&28 HE ATTACHED CHECK IS IN PAYMENT FOR rrEMS DESCRIBED ABOVE. ~ 1OO_ OO 1 OO_ OO iBP OEDEE COl · Ot~ 33 :AVENUE FIRST ASHLAND' =DAYS ,' ],88 ], :~ q," m:Oh],SO3,,°,~5m: 008 [, [, ~, ~11" WELL NAME .,~,,~'' 2., ;/'PROGRAM: exp dev,~ redrll serv wellbore seg ann. disposal para req WELL PERMIT CHECKLIST COMPANY i FIELD & POOL ~ b"'2-.~'/o~ INIT CLASS !ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in ddlling unit ............ 8. If deviated, is wellbore plat included ............. ·.. 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit canbe issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductorstdng provided ......... . .......... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons ..... ' ..... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. AREA N N N N N N N N N N N N UNIT# -K,z~!i~ /? ~r2..~ ON/OFF SHORE o4.) GEOLOGY 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ....... ; ...... 23. If diverter required, does it meet regulations .......... 24. Drilling.fluid program schematic & equip list adequate.. ~ . . 25. BOPEs, do they meet regulation ......... _ .._... ..... 26. BOPE press rating appropriate; test to [-{O~r~,_) psig. 27. Choke manifold complieS w/APl RP-53 (May 84) ......... 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued wlo hydrogen sulfide measures ...... Y 31. Data presented on potential overpressure zones . ...... Y,,,,N' 32. Seismic analysis of shallow gas zones ............. xPf N /L~, ~'-/. 33. Seabed condition surVey (if off-shore), ............ ' / Y N 34. Contact name/phone for weekly progress reports [exploratory ~o~rfly] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; ' (C) will not impair mechanical integrity of the Well used for diSposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY:'" COMMISSION: ENGINEERING:. UIC/Annular Comments/Instructions: 0 Z 0 c:~soffice\wordian~iana\checklist (rev.' 11101//00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the histo .fy file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. ., No special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Feb 26 13:10:46 2002 Reel Header Service name ............. LISTPE Date ..................... 02/02/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 02/02/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING MPC-24 500292302000 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 22-FEB-02 MWD RUN 1 AK-MM-ii117 D. LABRECQUE D. FERGUSON MWD RUN 2 AK-MM-Ii117 D. LABRECQUE J. PYRON MWD RUN 3 AK-MM-ii117 P. ROGER J. PYRON 10 13N 10E 1171 2446 44.80 16.20 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 20.000 116.0 8.500 9.625 5068.0 3RD STRING PRODUCTION STRING # REMARKS: 6.125 7.000 7680.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . 3. MWD RUN 1 COMPRISED DIRECTIONAL AND DUAL GAPIMA RAY (DGR, UTILIZING GEIGER-MUELLER TUBE DETECTORS). DGR DATA FROM THE BASE OF THE CONDUCTOR TO ABOUT 1944'MD WERE ACQUIRED WHILE RIH AFTER A TRIP TO ADD THE DGR TO THE BHA. 4. MWD RUNS 2 AND 3 COMPRISED DIRECTIONAL; DGR; AND ELECTROMAGNETIC WAVE RESISTIVITY - PHASE 4 (EWR4) . MWD RUN 3 ALSO INCLUDED STABILIZED LITHO- DENSITY (SLD) AND COMPENSATED THERMAL NEUTRON (CTN) . 5. DIGITAL AND LOG DATA ONLY ARE SHIFTED TO THE CASED-HOLE WIRELINE GAMMA RAY LOG RUN ON 2 AUGUST 2001. ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1-3 REPRESENT WELL MPC-24 WITH API# 50-029-23020-00. THIS WELL REACHED A TOTAL DEPTH OF 8404'MD/7226'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) SLIDE = NON-ROTATED INTERVALS SLDSLIDE = NON-ROTATED INTERVALS ACCOUNTING FOR SENSOR-TO-BIT DISTANCE PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: MUD SALINITY: FORMATION WATER SALINITY: FLUID DENSITY: MATRIX DENSITY: LITHOLOGY: $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 11.5 PPG - 11.8 PPG 700PPM CHLORIDES 11,000 PPM CHLORIDES 1.0 G/CC 2.65 G/CC SANDSTONE Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP RPX RPS RPM RPD FET NCNT FCNT NPHI PEF RHOB DRHO $ START DEPTH 112.0 117 0 5027 0 5027 0 5027 0 5027 0 5027 0 7587 5 7588 0 7588 0 7603 0 7682 5 7682.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 112 0 7263 7268 7274 7276 7307 7335 7348 7364 7388 7395 7412 7422 7435 7457 7477 7479 7485 7489 7492 7517 GR 108 5 7260 0 7264 5 7269 0 7273 0 7304 0 7331 5 7343 5 7359 5 7385 5 7392 0 7410 0 7419 0 7431 0 7453 0 7473 5 7475 5 7481 5 7485 5 7489 0 7514 0 STOP DEPTH 8344 0 8404 0 8351 0 8351 0 8351 0 8351 0 8351 0 8296 5 8297 0 8296 5 8311 5 8311 5 8311 5 EQUIVALENT UNSHIFTED DEPTH 7531 7534 7539 7541 7546 7551 7570 7586 7602 7609 7645 7683 7691 7696 7703 7714 7716 7733 7738 7756 7764 7773 7782 7789 7799 7805 7814 7824 7826 7840 7850 7855 7862 7874 7881 7891 7920 7930 7941 7944 7957 7971 7975 7981 7988 7995 7996 8010 8017 8030 8044 8052 8061 8075 8078 8083 8089 8105 8119 8151 8163 8172 8179 8186 8197 7527 7530 7535 7538 7542 7548 7567 7583 7599 7607 7641 7681 7688 7693 7702 7711 7713 7729 7736 7755 7762 7773 7782 7788 7798 7805 7813 7824 7826 7838 7848 7854 7860 7872 788O 7889 7917 7925 7933 7939 7954 7965 7970 7975 7983 7989 7992 8005 8012 8025 8040 8047 8057 8071 8074 8078 8085 8099 8112 8146 8158 8167 8175 8182 8193 8204 0 8213 8222 8253 8274 8282 8290 8404 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: 8201 5 8210 5 8220 0 8253 0 8276 0 8284 5 8292 5 8406 0 BIT RUN NO MERGE TOP MERGE BASE 1 112.0 5073.0 2 5073.0 7692.5 3 7692.5 8404.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 Name Service Unit DEPT FT ROP MWD FT/H GR MWD API RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HOUR NPHI MWD PU-S FCNT MWD CNTS NCNT MWD CNTS RHOB MWD G/CM DRHO MWD G/CM Min 112 0.38 23 16 0 64 0 65 0 62 0 67 0 15 9 76 105.2 13478.7 2.053 -0.222 Max Mean Nsam 8404 4258 16585 549.08 153.847 16575 297.98 90.458 16465 1828.68 3.63822 6649 1879.55 4.62377 6649 2000 21.1521 6649 2000 32.213 6649 70 2.6388 6649 71.94 37.4735 1418 1366.9 306.905 1419 39102.6 21216.6 1419 3.207 2.45013 1259 0.31 0.045336 1259 First Reading 112 117 112 5027 5027 5027 5027 5027 7588 7588 7587.5 7682.5 7682.5 Last Reading 8404 8404 8344 8351 8351 8351 8351 8351 8296.5 8297 8296.5 8311.5 8311.5 PEF MWD BARN 3 . 01 18 . 52 7.3663 1418 7603 8311.5 First Reading For Entire File .......... 112 Last Reading For Entire File ........... 8404 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 112 . 0 5010 . 0 ROP 117 . 0 5073 . 0 $ LOG HEADER DATA DATE LOGGED: 17-JUL-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 5073.5 TOP LOG INTERVAL (FT) : 112.0 BOTTOM LOG INTERVAL (FT) : 5073.5 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 19.0 MAXIMUM ANGLE: 31.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PBO1983HG8 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT) : 116.5 BOREHOLE CONDITIONS MLTD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Spud Mud 9.40 90.0 8.9 8OO 7.4 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD010 API 4 1 68 4 2 ROP MWD010 FT/H 4 1 68 8 3 .0 98.6 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 112 5073 2592.5 9923 GR MWD010 API 23.16 135.24 72.8084 9797 ROP MWD010 FT/H 2.31 549.08 165.212 9913 First Reading 112 112 117 Last Reading 5073 5010 5073 First Reading For Entire File .......... 112 Last Reading For Entire File ........... 5073 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPS RPM FET RPX RPD ROP $ 5010 5 5027 0 5027 0 5027 0 5027 0 5027 0 5073 5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: STOP DEPTH 7654 5 7647 5 7647 5 7647 5 7647 5 7647 5 7692 5 21-JUL-01 Insite 66.16 Memory 7692.5 5073.5 7692.5 29.4 56.3 TOOL NUMBER PB02084HWRG6 PB02084HWRG6 8.500 5068.5 LSND 10.50 44.0 9.0 8OO 4.8 4.000 2.031 65.0 134.6 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 3.800 4.250 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 65.0 65.0 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR Min 5010.5 1.82 45 09 0 64 0 65 0 62 0 67 0 15 Max Mean Nsam 7692.5 6351.5 5365 383.2 153.265 5239 297.98 118.459 5289 1828.68 3.48053 5242 1879.55 4.50136 5242 1810.24 4.82234 5242 2000 20.1574 5242 70 1.81318 5242 First Reading 5010.5 5073.5 5010.5 5027 5027 5027 5027 5027 Last Reading 7692 5 7692 5 7654 5 7647 5 7647 5 7647 5 7647 5 7647 5 First Reading For Entire File .......... 5010.5 Last Reading For Entire File ........... 7692.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. 3 .5000 BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE NCNT NPHI FCNT PEF RPX RPS RPM FET RPD GR RHOB DRHO ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 7587 5 7588 0 7588 0 7603 0 7648 0 7648 0 7648 0 7648 0 7648 0 7655 0 7682 5 7682 5 7693 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): STOP DEPTH 8296 5 8296 5 8297 0 8311 5 8351 0 8351 0 8351 0 8351 0 8351 0 8344 0 8311 5 8311 5 8404 0 25-JUL-01 Insite 66.16 Memory 8404.0 7692.5 8404.0 21.6 31.4 TOOL NUMBER PB02041GRHA4 PB02041GRHA4 PB02041GRHA4 PB02041GRHA4 6.125 7679.5 Baranex/Poly 11.50 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HOUR 4 1 68 NPHI MWD030 PU-S 4 1 68 FCNT MWD030 CNTS 4 1 68 NCNT MWD030 CNTS 4 1 68 RHOB MWD030 G/CM 4 1 68 DRHO MWD030 G/CM 4 1 68 PEF MWD030 BARN 4 1 68 42.0 8.8 70O 3.8 2.050 1.058 1.340 2.950 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 72.0 145.8 72.0 72.0 Name Service Unit Min Max DEPT FT 7587.5 8404 ROP MWD030 FT/H 0.38 205.86 GR MWD030 API 41.94 193.91 RPX MWD030 OHMM 0.68 53.29 RPS MWD030 OHMM 1.01 406.83 RPM MWD030 OHMM 1 2000 RPD MWD030 OHMM 1.02 2000 FET MWD030 HOUR 0.4801 69.3575 NPHI MWD030 PU-S 9.76 71.94 FCNT MWD030 CNTS 105.2 1366.9 NCNT MWD030 CNTS 13478.7 39102.6 RHOB MWD030 G/CM 2.053 3.207 Mean Nsam 7995.75 1634 76.817 1423 108.452 1379 4.22574 1407 5.07983 1407 81.9911 1407 77.128 1407 5.71481 1407 37.4735 1418 306.905 1419 21216.6 1419 2.45013 1259 First Reading 7587.5 7693 7655 7648 7648 7648 7648 7648 7588 7588 7587.5 7682.5 Last Reading 8404 8404 8344 8351 8351 8351 8351 8351 8296.5 8297 8296.5 8311.5 DRHO MWD030 G/CM PEF MWD030 BARN -0.222 0.31 3.01 18.52 0.045336 7.3663 1259 7682.5 8311.5 1418 7603 8311.5 First Reading For Entire File .......... 7587.5 Last Reading For Entire File ........... 8404 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/02/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/02/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File